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MINISTER OF ENERGY AND MINERAL RESOURCES

REPUBLIC OF INDONESIA

MINISTER OF ENERGY AND MINERAL RESOURCES REGULATION

NUMBER 04 OF 2009

CONCERNING

ELECTRIC POWER DISTRIBUTION CODES

BY THE GRACE OF GOD ALMIGHTY


Considering:

a. that the power distribution system has been developed and supported by the electricity supply

business, so the need for rules of distribution of electricity to create electrical power distribution

systems which are integrated, efficient, safe, reliable and quality;

b. that based on the considerations as referred to in letter a, it is necessary to stipulate Regulation of

the Minister of Energy and Mineral Resources concerning the Regulation on Electric Power

Distribution;

Bearing in mind:

I. Law Number 15 Year 1985 on Electricity (State Gazette of the Republic of lndonesia year 1985 No.

74, Supplement to State Gazette Number 3317 lndonesia);

2. Government Regulation Number 10 Year 1989 on Electricity Supply and Utilization (State lndonesia

1989 No. 24, Supplement to State Gazette Number 3394 lndonesia) as has been amended twice by

Government Regulation Number 26 Year 2006 (State Gazette of the Republic of lndonesia Year 2006

Number 56, Supplement to State Gazette of the Republic of lndonesia Number 4628);

3. Presidential Decree No. 187lM year 2004 dated October 20, 2004 as has been amended several

times and the latest amended by Presidential Decree No. 77lP Year 2007 dated August 28, 2007;

4. Regulation of the Minister of Energy and Mineral Resources No. 0030 of 2005 dated July 20, 2005

regarding Organization and Working Procedure of Ministry of Energy and Mineral Resources;

DECIDED:

To Stipulate: REGULATION OF THE MINISTER OF ENERGY AND MINERAL RESOURCES CONCERING THE

POWER DlSTRlBUTION CODES.

Article 1

Electric Power Distribution Codes are as set out in Annex which is an integral part of this Minister

Regulation.


Article 2

Electricity Distribution Codes as referred to in Article 1 shall be adhered to by all electricity supply

businesses operator and consumers of electricity who are connected to the Electric Power Distribution

System.

Article 3

Electricity Distribution Codes may be reviewed as needed.

Article 4

This Ministerial Regulation shall come into force on the date of enactment.

For public cognizance, it is ordered that this Minister regulation be promulgated in the State Gazette of

the Republic of Indonesia.

Stipulated in Jakarta

on February 20, 2009


Signed

Purnomo Yusgiantoro

Promulgated in Jakarta

on February 20, 2009

MINISTER OF JUSTICE AND HUMAN RIGHTS

REPUBLIC OF INDONESIA,

Signed

ANDl MATTALATTA

STATE GAZETTE OF THE REPUBLIC OF INDONESIA NUMBER 25 OF 2009


ATTACHMENT TO THE REGULATION OF MINISTER OF ENERGY AND MINERAL RESOURCES

NUMBER : 04 OF 2009

DATE : 20 FEBRUARY 2009

ELECTRIC POWER

DISTRIBUTION CODES

DEPARTMENT OF ENERGY AND MINERAL RESOURCES

2009


TABLE OF CONTENT

CHAPTER I INTRODUCTION.

CHAPTER II DISTRIBUTION CODE. (DC)

DC 1.0. Definitions.

DC 2.0. Scope

CHAPTER III DISTRIBUTION MANAGEMENT CODE (DMC)

DMC 1.0. The objectives.

DMC 2.0. Distribution Code Management Committee (KMAD)

DMC 3.0. Membership of KMAD

DMC 4.0. Organizational Structure of KMAD

DMC 5.0. Work Period KMAD Membership.

DMC 6.0. Sub-Committee

DMC 7.0. Meeting Time of KMAD

DMC 8.0. KMAD expenses.

DMC 9.0. Changes in Distribution Code.

DMC 10.0. Settlement of Disputes.

DMC 11.0. Enforcement of Distribution Code.

DMC 12.0. The report.

CHAPTER IV CONNECTION CODE-(CC)

CC 1.0. The objectives.

CC 2.0. Limitation of Connection Pont.

CC 3.0. Distribution System Technical Requirements

CC 4.0. PSD and Consumer Equipment Requirements

Equipment Requirements and Standards Used in Connection Distribution Point

CCL 1.0. General.

CCL 2.0. Requirements associated with the PSD and Consumer on Connection Point

CC 5.0. Connection procedures from the PSD with PD and PD with the Customer.

CC 6.0. Responsibilities of PD.

CHAPTER V OPERATING CODE-(OC)

OC 1. 0. Objectives .

OC 2.0. Responsibilities

OC 3.0. Distribution Protection


OC 4.0 Load Settings

OC 5.0 Emergency.

OC 6.0 Recovery Procedures.

OC 7.0 Testing and Inspection

OC 8.0 Inspection and Permissions to enter the Installation Location

OC 9.0 Communication and Reporting Procedures.

OC 10.0 Limits of responsibility of Distribution System Maintenance

OC 11.0 Preparation Procedure and Implementation of Maintenance Works

OC 12.0 Procedures on Occupational Health and Safety (K3)

CHAPTER VI PLANNING CODE-PC

PC 1.0. Objectives

PC 2.0. Responsibilities of All Parties

PC 3.0. Development of Distribution System Planning Study.

PC 4.0. Planning Data

PC 5.0. Spatial Planning

PC 6.0. Data needs.

CHAPTER VII SETTLEMENT CODE -(SC)

SC 1.0. Objectives

SC 2.0. Terms of the Transaction.

SC 3.0. Readings and Payments

SC 4.0. Dispute Settlement of the Transactions

SC 5.0. Settlement Process Audit Procedures

CHAPTER Vlll METERING CODE-(MC)

MC 1.0. Objectives

MC 2.0. Measurement Criteria.

MC 3.0. Meter Equipment Requirements

MC 4.0. Commissioning

MC 5.0. Post commissioning Tests

MC 6.0. Sealing and Reprogramming.

MC 7.0. Examination of Data Meter and Equipment.

MC 8.0. Measurement Equipment Security.

MC 9.0. Exceptions and Deadline

MC 10.0. Other provisions

GLOSSARY


CHAPTER l

INTRODUCTION

Electricity Distribution Code is an integral part of Regulation of the Minister of Energy and Mineral

Resources No. 04 of 2009 dated February 20, 2009 on Electric Power Distribution Code.

Electric Power Distribution Code is a set of rules and requirements to ensure the safety, reliability and

operations and development of an efficient distribution system to meet increased electricity demand.

Electric Power Distribution Code is based on current conditions, to be applied to all businesses in the

distribution system, i.e. Suppliers of Distribution Systems (Power Grid and Small and Medium Scale Power

Plant), Distribution Operator, Consumers, and Resellers whose installation is directly connected to the

distribution system.

The operator of distribution system shall meet in all provisions of Electricity Distribution Codes as the

basis for the installation operation of power supply owned. In addition, provisions on Electric Power

Distribution Code will provide clarity regarding the obligations of each business operators in the


Electric Power Distribution Code is a dynamic document so it should always be updated by the

Management Committee of Distribution Code along with the development of distribution system

conditions and business structures and changes in the electrical system complexity.

Electric Power Distribution Code is equipped with a glossary which is an integral part of the Electric Power

Distribution Code.


CHAPTER II

DISTRIBUTION CODE - DC

DC 1.0. Definition

Electric Power Distribution Code, hereinafter referred to as Distribution Code is a set of rules,

requirements and standards to ensure the safety, reliability and operations and the development of an

efficient distribution system to meet increasing electricity demand.

Distribution Code consist of:

a. Distribution Management Code.

b. Grafting Code.

c. Operating Code.

d. Planning Code.

e. Settlement Code.

f. Measurement Code.

DC 2.0. Scope

Scope of Distribution Code apply to all transactions and Suppliers interactions on Distribution Systems

(Power Grid and Small and Medium Scale Power Plant), Distribution Operator(PD),

Consumers, and Resellers as described in the following Scheme of Distribution System:

SCHEME OF DISTRIBUTION SYSTEM


CHAPTER Ill.

DISTRIBUTION MANAGEMENT CODE –(DMC)

DMC 1.0. Objectives

Distribution Management Code is a rule and procedure that aims to:

a. ease monitoring of the suitability of Distribution Code;

b. ensure that all Parties are represented in the review and make recommendations if there are changes

to the Distribution Code;

c. establish a dispute resolution process and the enforcement of Distribution Code.

DMC 2.0. Distribution Management Committee Code

To run the Distribution Code it is necessary to form the Management Committee for Distribution Code,

hereinafter referred as KMAD with the following tasks:

a. monitor the implementation of the Distribution Code;

b. evaluate and review the administration of Distribution Code, if necessary;

c. study the proposed changes to Distribution Code;

d. resolve differences in understanding and/or disputes relating to the Distribution Code;

e. collect and/or publish information deemed necessary without violating any confidentiality, in a special

publication which is used for the purpose of distribution Code;

f. Disseminate the Distribution Code or issue necessary recommendations in writing;

g. form the Sub Committee and the Secretariat as required.

DMC 3.0. KMAD Membership

KMAD is formed by the Director General of Electricity and Energy Utilization with membership

representing the parties, namely:

a. PD represented by a maximum of 5 (five);

b. PLN head office is represented by 2 (two);

c. PSD represented by 3 (three), each 2 (two) of the Grid and 1 (one) out of PSKM;

d. large consumers represented 2 (two) persons

e. professional organizations in the field of electricity represented by 1 (one);

f. Directorate General of Electricity and Energy Utilization, represented by 1 (one);

g. Consumers Institute represented 1 (one).

KMAD members must have adequate background and experience so that they can understand and can

evaluate aspects related to the operation, planning, development and commercial distribution systems.


DMC 4.0. Organizational Structure KMAD

a. KMAD led by the Chairman.

b. KMAD consist of 1 (one) as Chairman and member, 1 (one) as deputy chairman and member, 1 (one)

as secretary and the members and at most 12 (twelve) members.

c. KMAD Membership is valid for 3 (three) years, and can be re-elected. Chairman elected by members

through a specific mechanism for the establishment and the first time determined by the Director

General of Electricity and Energy Utilization.

d. In carrying out its duties, KMAD assisted by the Sub Committee and the Secretariat. Sub Committee

consisting of at least Sub-Committee on Planning and Operations Sub-Committee.

DMC 5.0 Work Period KMAD Membership

the working period of KMAD Chairman is for 3 (three) years and may be reelected for the next work

period. The chairmanship KMAD automatically expire if the party concerned permanently absent or no

longer working for the company / agencies represented and immediately elected his successor. While

working period for KMAD Members automatically terminate if there is an official letter from company /

agencies about withdrawal from KMAD membership concerned or concerned permanently absent or no

longer working for the company they represent and be elected his successor immediately.

DMC 6.0. Sub-Committee

KMAD form a Sub Committee on Planning and Operations Sub-Committee, and if required to establish

another subcommittee either a temporary or permanent.

DMC 6.1 Planning Sub Committee

Planning Sub Committee has the task:

a. Reviewing the annual development plan of distribution systems to ensure adequate provision of

reliability and efficiency of operations for the future;

b. review and recommend follow-up project proposals of distribution system development.


DMC 6.2.

Operation of the Sub Committee

Operation of the Sub Committee has the task:

a. reviewing the annual report of the operation planning of distribution systems, and

b. recommend changes in operating procedures for reliability and economical operation of the


Sub-Committee shall conduct meetings every 3 (three) months to evaluate the realization of the

operation of 3 (three) months earlier.

DMC 7.0.

Meeting Time KMAD

a. KMAD can hold meetings for discussion of changes and / or disputes that occur any time.

b. Minimum of once of 1 (one) year KMAD hold a meeting to analyze and evaluate the implementation

of the Distribution Codes.

DMC 8.0.

KMAD costs

KMAD must prepare the operating budget for next year every September.

Operational costs are charged to the business operator of KMAD Distribution Codes and shall be further

regulated by KMAD.

DMC 9.0.

Distribution Code Changes

a. Proposed changes shall be submitted in writing to KMAD.

b. KMAD will study the proposal.

c. Proposed changes will be submitted in writing by KMAD to the Parties to obtain input / comments in

writing.

d. the Sub-Committee is ordered by KMAD the to examine, review and propose if the proposal of

changes is accepted / rejected to be determined by KMAD.

e. KMAD to make changes recommendations and propose to the Minister of Energy and Mineral

Resources through Director General of Electricity and Energy Utilization to be determined by the

Minister of Energy and Mineral Resources.


DMC 10.0. settlement of Disputes

a. Notice of the dispute shall be submitted in writing to KMAD.

b. KMAD will study the notice.

c. Any dispute resolved by KMAD after hearing the responses from each party and be settled within no

later than 3 (three) months.

d. KMAD will establish dispute settlement decisions are final.

DMC 11.0. Enforcement Codes of Distribution

If KMAD believes there who violates the Codes of Distribution and the action deemed necessary KMAD

got the right to take action as follows:

a. KMAD will send a written warning to the party who commits an offense with an explanation of the

rules which are violated and the actions to be taken by the party break;

b. parties can use that violates the right of reply or take action recommended by KMAD the maximum

period I (one) month after receiving a written warning;

c. if KMAD approved the contents of the right of reply then the offense is considered closed;

d. KMAD if not approved the content of the right of reply then KMAD determined that the decision is

final.

DMC 12.0. Reports

a. Annual Report.

KMAD make a brief report of operational implementation of the Codes of Distribution to the

Directorate General of Electricity and Energy Utilization in March every year.

b. Important Events Reports

1) No later than 1 (one) week after an important event in the distribution system, PD sends a written

report to KMAD through the Operation Sub-Committee. The report contains details of the causes

and sequence of events as well as other relevant information such as number and duration of

power outages.

2) At least 1 (one) month after receipt of the report from the PD about important events, KMAD

decided sanctions or who should be responsible, in case there are those who violate the Codes of

Distribution.

c. Special Report :

If there is a special request from the Directorate General of Electricity and Energy Utilization, KMAD

must make a report on demand.


CHAPTER IV

CONNECTION CODE-(CC)

Connection Code is a rule that details about the installation of the electrical connection procedures and

requirements must be met both technical and operational by the PD, PSD and Consumers who connect or

be connected to the distribution system.

CC 1.0. Objective

Connection is the Objective of the Rule:

a. explain procedures, techniques and operational requirements that must be complied with by the PSD

and the Consumer before and when connected to the distribution system;

b. ensure that the PSD and the Consumer will only be connected to the distribution system if the

fulfillment of the requirements engineering and connection procedures and other requirements listed

in Connection Code;

c. ensure that the PSD, Consumer and PD have the same reference in the connection process.

CC 2.0.

Connection Point Limit

Limitation of connection points include:

a. Consumer Connection 400/230 Volt electrical voltage.

1) The connection point is located after the APP.

2) PD can determine the location of a connection point other than the items a.1. for special technical

and economical consideration.

b. 20 kV Consumer electrical voltage connection.

1) The point of connection is located after the APP.

2) PD can determine the location of a connection point other than the items b.1. for special

consideration is technically and economically.

c. Consumers of high voltage electrical connections.

1) The point of connection is located after the APP.

2) PD can determine the location of a connection point other than item c.1. for special technical and

economical consideration.

d. PSD connection.

1) The point of connection is located after the APP energy transactions from PSD to PD.

2) The point of connection can be made in addition to the PSD in item D.1. according to collective

agreement


CC 3.0. Distribution Technical System Requirements

a. All connection points following the distribution technical system requirements as follows:

1) the nominal system frequency is 50 Hz and have a normal frequency range between 493 Hz to

50.5 Hz.

2) voltage distribution system must be maintained at the boundaries of normal conditions of

maximum +5% and minimum -10% of nominal voltage.

3) a maximum total harmonic distortion is as the following table:

table 1

Maximum Limit of Harmonics Distortion - Voltage

Harmonics Distortion Individual Voltage (%)

Harmonics Distortion Individual Voltage (%)

3.0 5.0

table 2

Maximum Limit of Harmonics Distortion - Flows

Odd Harmonics, h H<11 11<h<17 17<h<23 23<h<35 35<h< TDD

Harmonics Distortion - Flows (%)

4.0 2.0 1.5 0.6 0.3 5.0

Note:

i. Harmonics Distortion Limit - Even Flow is 25% of the value in Table 2 above.

ii. Figures in the table apply to the number of harmonics (h) multiple of a frequency of 50 Hz.

4) Fluctuations in voltage at a high voltage connection point refers to the Codes of Distribution.

b. Distribution technical system requirements referred to in CC 3.0.a shall not apply during a fault

condition on the distribution system. And all the PD and PSD and Consumers are required to work

together to ensure that all distribution technical system requirements can be met.

CC 4.0. PSD and Consumer Equipment Requirements

CC 4.1. General Requirements

a. The entire equipment installed shall be operated and maintained in accordance with the technical

requirements of usage and distribution systems.

b. The whole equipment PSD, PD and Consumers must meet the requirements and standards provided

in these Terms and Standard Equipment Used at Connection Distribution Point, as follows:

Equipment Requirements and Standards Used to Connection Distribution Point


CCL 1.0. General

All equipment connected to the distribution system must meet the standards set in SNI. For standard

equipment that has not been set within the SNI, can refer to international standards such as ANSI, IEEE,

NEC, NEMA, IEC or refer to the standards set by the PD (e.g.: SPLN).

CCL 2.0. Requirements Relating to the PSD and the Consumer Connection Point

Any connection between PSD, PD and Consumers will be controlled by the protective device that is able to

break the short circuit current and overload current the connection points.

CCL 2.1. Setting Protection Equipment

a. Protection on the PSD installation and Consumers connected to the distribution system must meet

the minimum requirements standard release time for interference.

b. Protection settings on the installations of PSD, PD, and the Customer shall be coordinated in order to

reduce the influence of disturbances on the distribution system.

CCL. 2.1.1 20 kV Network Protection

a. Protection system depends on the pattern of the system applied to the distribution system in each PD

(e.g.: Security Pattern System 6 kV and 20 kV SPLN 52-3: 1983).

b. Conductor terminals with power breaker shall be equipped with relay protection at least against short

circuit interruption

CCL. 2.1.2. Network Protection Low Voltage (400/230 Volt)

All low voltage network (400/230 Volt) connected to the distribution system must be equipped with load

divider and protection in accordance with SNI-04-0225-2000: General Requirements for Electrical

lnstallation 2000.

CCL. 2.1.3 protection PSKM

Protection of all PSKM connected on distribution system must be coordinated with the protection of

distribution systems are equipped with at least a short-circuit current protection phases and phase-

ground, power back protection, voltage protection more/less and frequency protection more/less.

2.1.4 CCL. Distribution Transformer Protection

All transformers which are connected to the distribution system shall be equipped with lightning

protection equipment and protective equipment against overload and short circuit current of the switch

or breaker fuser.


CCL. 2.1.5 Protection for Low Voltage Connection (400/230 Volt)

All PSD and Consumers directly connected to the low voltage network must be equipped with barrier and

protection against interruption of short circuit / overload automatic switches or safety of melting.

CC 4.2. PSD Equipment Requirements

a. PSD equipment should be able to operate in accordance with available capacity.

b. PSD must complete the means of communication that may be associated with PD for the purpose of

coordination of operation system.

c. Protection equipment owned by the PSD and PD should be coordinated.

CC 4.3. Consumer Equipment Requirements

Consumer's protection equipment should be coordinated with the protection that apply in the


CC 5.0. Connection Procedures of the PSD with PD and PD with Consumers

CC 5.1. Connection procedures PSD with PD

CC 5.1.1. Connection procedures Grid with PD

Valid Procedures refer to the Codes of Networking

CC 5.1.2. Connection procedures of PSKM with PD

Procedures that apply generally to all PSKM are as follows:

a. PSKM must notify to the PD that the commissioning was done on PSKM's installation and have

obtained the SLO from an accredited institution;

b. PSKM must provide data and setting of the protection pattern to be approved by PD;

c. PSKM submit an installation connection request to the distribution system in writing;

d. PSKM together with PD to check and test the connection point of distribution to ensure that all

equipment functioning properly in accordance with the usability and capacity;

e. after the administrative and technical requirements be met as well as cooperation agreements or

agreed to purchase electrical energy, then PD expressed its approval of the connection of the

installations belonging to the PSKM to distribution system in writing.


CC 5.2. Connection procedures between PD with Consumers

a. Consumers complete the administrative requirements.

b. Consumers passed the SLO from an accredited institution and / or electrical installation guarantee.

c. Consumers and the PD jointly checking against equipment / installation belonging to the Customer at

a connection point of distribution.

d. Consumers filed a request providing voltage to the PD after checking with equipment / installation

belonging to Consumers in the distribution connection point and has been found to comply with the

technical requirements of Connection Code by the PD.

e. PD can connect if equipment / installation meet the techniques requirements of Connection Code.

CC 6.0. Responsibility of PD

Before giving the voltage at a connection point, the PD must:

a. ensure that the installation of the PSD and the Customer have met all the requirements as referred to

in CC 3.0. and CC 4.0.

b. convey to the PSD and Consumer information as follows:

1) a list of equipment and performance that is owned by PD at connection points;

2) the level of service provided by the PD to the Customer at the connection point;

3) distribution system SOP to the PSD.

CC 6.1. Connection Points Inspection

PD did inspection / checking and evaluation at a connection point to ensure that distribution system is

safe for operation. The results of inspections communicated in writing by the PD to PSKM and Large

Consumers.

CC 6.2. Distribution of Voltage On Connection Point

after PD issued approval of the connection to the PSKM and Consumers, then an agreement is made

between the PD and PSKM/Consumer on the procedure and timing of the voltage distribution.


CHAPTER V

OPERATING CODES (OC)

Codes of Operation explains the rules and procedures established to ensure human safety, equipment

safety, the environment and to ensure quality, reliability, operational efficiency and standards at a level

that can be maintained in the distribution system.

OC 1.0. Objective

The objective of this rule is to set things as follows:

a. operational responsibility of the PSD, PD and all distribution systems Consumers for safety and

reliability of distribution operations;

b. protection of distribution;

c. setting the load to overcome the shortage of supply of the PSD;

d. procedures to be followed by the PD, PSD, and the Consumer during emergencies;

e. restoration of distribution systems;

f. testing, monitoring, and inspection of the distribution system;

g. examination and admission to the installation location;

h. communication and reporting;

i. limits of responsibility in connection with maintenance activities;

j. coordinating the preparation and execution of maintenance work;

k. coordination of Occupational Health and Safety (K3).

OC 2.0. responsibility

This rule states the basic responsibility for the PSD, PD and Consumers for the safety and reliability of

distribution operations.

OC 2.1. Responsibilities and Obligations of Distribution Security

PD coordinate the distribution system operations to maintain the quality, reliability and security for the

distribution for PSD and consumer interests. PSD and the Customer shall be obliged to work with PD in

terms of testing of equipment and distribution facilities.

OC 2. I.I. Responsibility PD

To optimize the distribution system operating with a level of quality and good reliability, PD responsible

for:

a. maintain, monitor and maintain the quality and reliability in the distribution system;

b. maintain all equipment of distribution system;

c. guarantee to always follow the distribution system operating procedures which are safe and

economical;

d. make a list of Big Consumers which can reduce the burden voluntarily and / or turn on emergency

units (backup power plant).


e. create a priority list of feeders to be extinguished manually (Manual Load Shedding);

f. create a priority list of feeders to be extinguished corresponding schema, UFR load shedding;

g. have standard operating procedures (SOP) that must be adapted to the development of the operating

system distribution;

h. maneuvering distribution network.

OC 2.1.2. Responsibility for PSD

PSD is obliged to ensure the safety, quality, reliability and quantity of electricity supply to the distribution

system.

PSD is responsible for:

a. coordinating maintenance plan, repair and development of PSD equipment that can affect the safety,

quality, reliability and continuity of supply of electricity;

b. immediately inform the PD of PSD operational conditions that will affect the disruption of quality,

reliability and continuity of supply of electricity;

c. provide data for the purpose of calculation of short circuit at a connection point for the coordination

of protection, among others, to ensure the reliability of the system and adjustments distribution

equipment capacity.

OC 2.1.3. Big Consumer Responsibility

Big consumers are responsible to participate in maintaining the integrity of the system, by the way:

a. maintain the flicker limit with numbers of voltage Depression on short Circuit (DTHS) does not

exceed 3% of nominal voltage.

b. individual harmonic distortion does not exceed 3% and the total harmonic distortion not exceed 5%. If

the above limit is exceeded, PD is entitle to check and take the necessary action to correct deviations

occur;

c. participate to reduce the burden of deficit;

d. disconnect the load when ordered by the PD or automatically with the under frequency relays and /

or under voltage relays to protect the security of energy supply of electricity.

OC 3.0. Distribution Protection

adequate Distribution protective devices and coordination of protection needed to protect distribution

equipment and prevent the widespread of disturbances on the distribution system. Distribution

protection procedures are as follows:

a. PSD and the Customer shall submit any changes to the pattern of protection to the PD for the

coordination of protection;

b. protection pattern of distribution should be according to the provisions of the applicable standards in

Indonesia.


OC 4.0. Load Settings

OC 4.1. Coordination Load Settings When Power Deficit

If for any reason Grid issued a power supply shortage (deficit), then the PD along with Big Customer will

perform in the following order:

a. PD coordinate Big Consumers to reduce the burden or turn on the emergency unit (power backup) -

owned by Big Consumer voluntarily in accordance with appropriate SOPs agreed upon;

b. if the load reductions referred to in item a has not been able to overcome the power deficit then

voltage reduction will be done;

c, if the voltage reductions as referred to in point b has not been able to overcome the power deficit

then the load release is carried out manually.

When Grid has expressed the normal system conditions the PD immediately restore and normalize the

medium voltage system and notify the Big Consumers.

OC 4.2. Load Shedding through the UFR

In order to anticipate system disorder that causes the power deficit then to maintain the integrity of the

system, it is designed using the UFR load reduction scheme as follows:

a. sequence and a large load which is released by the UFR is considering operational needs and vital

loads;

b. Grid with PD determine the load to be released per area per stage for Load Shedding through UFR;

c. after a normal condition, PD should strive to quickly restore critical facilities which are included in the

Load Shedding.

OC 5.0. Emergency

Distribution system emergencies occur when:

a, shortage of electricity supply or distribution system voltage is not normal;

b. disorder that causes the separation of distribution system outages and or partial or total blackout;

c. severe weather, earthquakes, fires, riots, etc.. that threaten the security of the distribution.

PD, PSD and Consumers shall comply with the procedures referred to in OC 5.2. and OC 5.3. to restore the

distribution system as quickly as possible to the normal or standby network operation condition.

OC 5.1. Emergency Distribution Procedures Guidelines

PD create and inform the distribution of emergency procedures and make list of parties who are notified

in an emergency including name, address and contact phone number.

OC 5.2. Emergency Distribution Statement

PD will declare emergency distributions conditions in case of conditions as referred to in OC.5.0. letter a

up to c at least 1 x 24 hours after an emergency occurs.


OC 5.3. Distribution Emergency Condition Notification

Immediately after the emergency condition of distribution has been declared, the PD will:

a. prepare the load that can be extinguished by priority to overcome the shortage of electricity supply.

Large load which is extinguished is based on the load target specified by the Grid;

b. notify the Customer of the emergency condition.

OC 5.4. Preparation of Emergency condition of Distribution

a. PD provides information to consumers in order to reduce the effect of disconnection of power supply

caused by:

1) natural disasters;

2) riots; or

3) events that can not be avoided,

b. conduct emergency condition of distribution simulations which is conducted of at least 1 (one) time a

year so that all responsible personnel trained in dealing with emergency distribution condition.

OC 6.0. Recovery Procedures

Recovery procedures are actions taken to restore the operating state of the fault conditions. For that

recovery SOP is needed to be established so that recovery can be done quickly and safely.

OC 6.1. The disruption in PSD side

a. If the disturbance in the PSD side resulted in interruption of power supply to the distribution system,

then the recovery procedure will be performed in accordance with mutual agreement between the

PSD and PD.

b. If the disturbance on the PSD side resulting passed the normal range of voltage and frequency, then

the PD will request information about the causes disruption of the PSD and asked for a recovery to

normal network operating conditions. Furthermore, the PD will inform the specific disorder to the

Large Consumers.

OC 6.2. The disturbances in Distribution System Side

If the disturbances in the distribution system side resulting in the operation of protection equipment 20

kV feeders, then the recovery procedure is performed following the SOP on the distribution system of

each PD.

OC 7.0. Testing and Inspection

This section sets out the activities procedures associated with testing and inspections. If deemed

necessary, the PD will perform testing of PSD equipment or Consumer.


OC 7.1. Testing

PD, PSD and Consumers have the right to test any equipment along with related equipment connection

point between PD, PSD and Consumers. Testing provisions are as follows:

a. if there is one party has a good reason and felt that the equipment which is operated by the other

party does not fulfill the Distribution Codes, then such party may request testing of the equipment by

giving written notice;

b. the two sides will cooperate in conducting testing as referred to in letter a;

c. cost of testing that emerge borne by the party requesting the test, unless the equipment tested is

found not to meet the Distribution Codes, then the cost of testing borne by the party being tested;

d. testing costs are not included losses due to interruption or reduction in power supply, but the PD will

minimize the losses in the testing process;

e. testing was conducted according to standard procedures that apply.

OC 7.2. Testing Equipment Protection

a. PSD and consumers which are connected at a connection point will work with PD in the examination

or testing of protection equipment periodically.

b. PD, PSD and Consumer shall bear their respective costs of testing on the system of protection, unless

there is another deal.

OC 7.3. Consumer Owned Equipment Testing

If Consumers carry out testing of his equipment that impact the reliability and security of the distribution

system operations and the measurement at a connection point, then the Customer must obtain prior

approval of the PD.

OC 7.4. Notice of Testing

PSD or consumers who will conduct the test on his equipment associated with a connection point, is

obliged to submit notification in writing to the PD within 5 (five) working days prior to testing.

Such notification shall contain:

a. details of the testing;

b. approximate start and end time of testing;

c. introduction of the equipment under test;

d. system conditions required to conduct testing;

e. name of the officer in charge during testing.

PD may reject or reschedule, by mutual agreement, if the distribution system condition does not allow.


OC 8.0. Inspection and Permissions to enter the Installation Location

OC 8.1. Permissions to enter the installation location

a. PSD and the Consumer shall provide direct access for PD officer who will conduct an audit of assets

belonging to PD.

b. the PSD or Consumers can enter PD's installation after obtaining written permission from the PD.

OC 8.2. Right to Inspect

a. PD, PSD and Consumers have the right to inspect the equipment with each other at a connection

point. The right to inspect only applies to efforts to ensure conformity with the Codes of Distribution.

b. If one party suspected that the other party does not comply with Code of Distribution and that has an

adverse effect on the operation of the distribution system, then such party may file an examination of

the suspected equipment.

c. party who inspected will appoint qualified personnel to accompany the representative Person that

checks to enter the examination site.

d. Parties that checks will ensure that its representatives qualified to carry out the inspection.

OC 8.3. Inspection by PD

a. PD can inspect PSKM and Consumers equipment connected to the distribution system according to

the provisions referred to in OC 8.2. to:

1) assess the suitability of PSKM or Consumer equipment connected to the distribution system as

their operational obligations of the Codes of Distribution;

2) investigate any potential threats that may happen to the security of the distribution system.

b. During the inspection, the PD officer;

1) take no action that could cause damage to PSKM or Consumer equipment connected to the

distribution system;

2) only operate PSKM or Consumer equipment connected to the distribution system to the extent

required and approved by PSKM or Consumer;

3) comply with the internal regulations of the PSKM or Consumer with respect to employment,

health and safety.

c. PSKM and Consumers appoint officers who have the competence to accompany PD officers during

inspection.


OC 9.0. Communication and Reporting Procedures

a. For the purposes of safe and reliable distribution system operation then PSKM, PD and Consumers

need to communicate on any network operating conditions. PD is responsible for communicating the

events on the distribution system to PSKM or Consumers who are affected by these events.

b. PSKM or the Customer is obliged to notify the PD, with regard to operation and maintenance plan as

well as disorders that affect the operation of distribution systems. The implementation of

communication procedures will be outlined in communication and reporting SOP as agreed by the

parties concerned.

OC 10.0. Limits of Liability to the Distribution System Maintenance

a. Limits and responsibilities of maintenance of an asset based on the principle of ownership of assets

such as the maintenance scope of distribution system is started from cells of 20 kV outgoing

substations (GI), 20 kV Medium Voltage Network (JTM), Distribution Substation, Low Voltage Network

(JTR), External Connection (SL) up to and Measuring Tool Delimiter (APP) in the Customer’s building,

including SCADA and communications facilities.

b. Exceptions to the provisions referred to in letter a can be done separately in accordance with the

agreement between the asset owner and maintenance operator which is set forth in a separate

agreement.

OC11.0. Preparation and Implementation Procedure for Maintenance Works

Implementation of maintenance work on distribution system involving multiple parties that require

coordination with each other. Parties involved in the implementation of distribution systems maintenance

work are PSD, PD and Consumers.

OC 11.1. PSD

the PSD is responsible for implementing network and installation of electric power maintenance within

the limits of ownership. Maintenance work on the upstream side sometimes require power blackout on

the distribution side and vice versa, there is work on the distribution side that requires electricity blackout

of the PSD, so that coordination between the PSD and PD needs to be done.


OC 1 1.1.1. Preparation of Maintenance Work

a. PSD submit plans for maintenance work on the side of the PSD which affects the distribution system.

b. The maintenance work scheduled submitted to the PD no later than 2 (two) weeks before the day of

execution.

c. Maintenance work which resulted in electric power blackout to the distribution system can only be

implemented after approval of the PD.

d. PSD receives notifications of maintenance approval from the PD no later than 1 (one) week prior to

the implementation of maintenance.

OC 11. I.2. Implementation and Responsible for Maintenance Work

a. On the day of the maintenance work on the upstream side related the electricity outages in

distribution system, person in charge of the work of the PSD should be coordinating with PD

b. the implementation Setting of the maintenance work is set in accordance with SOP agreed.

OC 11.2. PD

PD is responsible for the execution of maintenance work on distribution systems. In carrying out

maintenance work, the PD must coordinate with the PSD and the Consumer.

OC 11.2.1 Preparation of Maintenance Work

a. PD deliver maintenance schedule distribution system according to the PSD and Consumer needs.

b. PD informed the work plan that resulted in the electricity outages to the Customer no later than 24

(twenty four) hours prior to the outage.

OC. 11.2.2 Implementation and Maintenance Work Responsible Parties

a. Distribution system maintenance work can be carried out by a network outage or without a network

outage. Maintenance work with network outage as far as possible be avoided.

b. maintenance work can be carried out without power outage by using the facilities in the Work-in

voltage (PDKB) on Medium Voltage Air Line system (SUTM) and the Mobile Unit Substation (UGB) on

the Distribution Substation maintenance.


c. the network maneuver in order to perform network maintenance and normalization in accordance

with standard operating procedures that have been specified.

d. Implementation of maintenance work is supervised by a responsible person who meets certain

competency.

e. Work responsible person / Occupational safety coordinator is in charge to:

1) examine the readiness of the implementation of maintenance work either for working tools,

safety equipment or personnel;

2) coordinate with the network regulatory in order to maneuver the network to release tension and

network re-normalization;

3) examine that the work was actually completed and the network is safe from personnel and other

working tools for the voltage reloading.

f. Maintenance work can be done by third parties that meet certain qualifications and competence.

OC 11.3. Big consumers

OC 11.3.1 Preparation of Maintenance Work

a. Big consumers submit a written installation maintenance schedule that requires power outages to the

PD as needed no later than 2 (two) weeks before the day of execution by enclosing the reasons for

maintenance work is to be performed and the approximate duration of the job will be done.

b. PD will provide the approval in writing of the work schedule of at least 1 (one) week prior to the

implementation of maintenance.

OC 11.3.2 Implementation and Maintenance Work Responsible Parties

a. Implementation of maintenance work on the network and the installation of Big Consumers is

supervised by officers in accordance with their competences.

b. Work Responsible Party is to re- confirm of the proposed network outages, request for network

outages in the framework of the implementation of maintenance work on the installation of the Big

Consumers to the PD on the day of execution.

c. Work Responsible Party is to supervise the implementation of the work from preparation until the job

has been completed.

d. Responsible for the work request that normalized power flow back to the PD after work is completed.

OC 12.0. Safety and Occupational Health procedures (K3)

PSD, PD and Big Consumers, each is responsible for safety and health for the officer in carrying out

maintenance work on electric power network according to their responsibilities. Each party shall have

person in charge of the implementation of the K3. K3 responsible task, among others:

a. examine if the equipment complies with the standard K3;

b. examine if the condition of readiness and K3safety equipment used;

c. supervise if the use of K3 equipment is in a proper way during the execution of the work


CHAPTER VI

PLANNING CODE- (PC)

Distribution Planning Codes explain the rules to establish the liability of the PSD, PD and Consumers in the

development of distribution systems.

PC 1.0. Objectives

The objective of the Planning Code is:

a. to establish criteria and standards of planning design to manifest distribution system that is safe,

reliable and efficient;

b. to establish the necessary data from the PSD, PD and Consumers for the benefit of the development

of distribution systems;

c. to provide clarity and certainty for all PSD and Consumers, associated with the development plan

distribution system, to realize a secure distribution system, with quality and adequate levels of

reliability and operating efficiencies that can be justified.

PC 2.0. Responsibilities of Parties

a. PD responsibilities are:

1) analyze the impact of electrical facilities connection to the distribution system originating from

the PSD and consumers on the performance of distribution system operations;

2) identify and plan the development of distribution systems to ensure availability of supply to meet

load demand, the realization of the quality and supply reliability as well as the efficiency of

operations;

b. PSD and Consumers should work with PD in meeting the data needs for the purposes of distribution

system development plan for the realization of the expected distribution of operating performance.

PC 2.1. Planning Data Delivery

a. If there are connection plans or modification of the installation, PSD or Consumer who is connected to

the distribution system shall submit the relevant data and detailed.

b. PSD and Consumers at the beginning of each year shall submit the relevant historical data for the last

3 (three) years and outline planning data for the next 5 (five) years to the PD.

c. planning data as determined necessary must contain the information necessary by PD to evaluate the

impact of on the development of PSD and Consumers sides to the distribution system.

d. The planning data should provide the information necessary to conduct the development of a more

accurate distribution system. The data referred to include the parameters of the distribution and

protection system who are connected directly to or affects the distribution system and should be

adequate for the PD to conduct a study on the impacts associated with the connection point.

e. Planning data must be sent by the PSD and Consumer to the PD according to the following categories:

I) projection data load requirements;

2) loading data to electrical facility from the PSD;

3) PSKM capabilities data;

4) equipment data to be installed;

5) attached equipment data.


PC 2.2. Planning Data Collection and Rejuvenation

a. For a period of next 2 (two) years, no later than August 1, PD must collect and rejuvenate the

distribution planning data according to the following categories:

I) load requirements projection data;

2) loading data electrical facility from the PSD;

3) PSKM capabilities data;

4) the equipment data to be installed;

5) attached equipment data.

b. If there are changes to the planning data, the PSD and the Customer shall immediately inform the

changes to the PD no later than February 1 of the coming year.

PC 2.3. Evaluation Against Development Proposals with Impact Against Distribution Network

a. PD must conduct a review of development proposals submitted by the PSD and the Customer that

affect the distribution system.

b. PD must submit the results of the review include recommendations to the PSD and the Consumer.

c. PD must also convey to the PSD and Consumers on planned development of distribution systems that

will impact on the PSD and the Consumer.

PC 2.4. Distribution System Development Plan Preparation

a. PD must collect and process planning data sent by the PSD and Consumers into the load forecasting

data to be used as a distribution system development plan.

b. PD should consider economic growth and regional development plans of relevant agencies (including

the Central PLN).

c. The distribution system development plan includes:

1) load growth and energy forecast;

2) the proposed increase in capacity and site development of new substation (GI);

3) improvement of quality, reliability and efficiency of operation of distribution networks;

4) a summary of the technical and economical analysis performed for the development of

distribution systems.

d. Development plan for rural electricity distribution system to be coordinated with the Directorate

General of Electricity and Energy Utilization.

PC 3.0. Planning on Distribution System Development Review

Distribution system planning review to be performed include:

a. distribution system planning review conducted by the PD to ensure the safety, quality and reliability

of distribution systems, namely:

1) evaluation of project development program of distribution system;

2) evaluation of development proposals from the PSD and the Consumer,

b. distribution planning review should be conducted to review the impact on distribution system

regarding loads planning or equipment changes.


c. technical study as referred to in PC 3.1. up to. PC 3.4. and planning the necessary data as referred to

in PC 4.0. should be used in conducting distribution system planning studies.

d. distribution system planning analysis conducted by PD includes:

1) determination of an optimal design for the selection of the location and capacity of GI;

2) Determination of the optimum design for distribution system realization that meets the criteria of

quality and level of reliability and operating efficiency.

e. distribution planning study should be done using the cost approach to the Least Cost Planning.

PC 3.1. Voltage Drop Studies

a. The voltage drop studies should be performed to gain of the voltage rate at the connection point on

existing distribution system and the conditions of its development.

b. Voltage drop studies should be performed to evaluate the impact on the distribution system for

connection of the PSD, the Consumer and the addition of the distribution network.

PC 3.2. Short circuit Study

a. Short circuit only to determine the coordination of relay settings gradation between the PD and PSD

consumers installations.

b. Short circuit capacity of the equipment specified maximum of 500 MVA at 20 kV voltage side.

c. Three-phase short circuit should be made to all the nodes of the distribution system for the

coordination of relays.

d. Single phase short circuit to ground should be made to the node distribution system that ensured the

protection system can function properly.

e. PSD sends the results of short circuit of the three phase and a phase to ground periodically or there is

a change in the PSD system to the PD for the sake of safety equipment distribution system.

f. PD informs the consumer if there are changes in short circuit current 3 phase and a phase to ground.

PC 3.3. Distribution Losses Study

a. Technical level of losses in the distribution network is determined by the choice of conductor, cross-

sectional area and the specifications of the selected transformer.

b. distribution losses study should be conducted to identify the magnitude of losses on the distribution

of JTM, distribution substations and JTR in the distribution system.

c. distribution losses study should be conducted to determine the effect of the development of PSD,

Consumer and development of distribution systems on the efficiency of distribution system

operation.

PC 3.4. Distribution Reliability Studies

a. Degree of reliability in the distribution network is determined by the selection of system configuration

and Medium Voltage Cable Channels (SKTM) and SUTM which is adjusted with the load conditions

and the availability of investment.

b. the distribution reliability studies must be done to determine a reasonable level of reliability for the

relevant distribution system.


PC 4.0 Planning Data

Planning data includes energy and load forecasted data. PD developed forecasts of energy demand and

loads, including peak loads for 5 (five) years.

a. Data forecasts for the first year in the form of monthly, and the following 4 (four) years sufficient

energy forecasts and the annual load.

b. The following factors must be considered by the PD in preparing the load forecasts:

I) historical load data;

2) the trend of load growth;

3) important events;

4) the use of captive power;

5) interconnection with the nearest PD; and

6) other relevant factors (population growth, economic, urban design master plan).

PC 5.0 Spatial Planning

To facilitate the planning of the development of the distribution system, it is required that outlines the

spatial planning of Right of Way (ROW) and location of land or space for distribution substations and GI

are listed in the General Spatial Plan Areas.

PC 6.0. Data Needs

Data needs include:

a. Generating Unit Design Data

This section describes the technical design of the data requirements of each generator unit, including

general technical data, reactance and resistance data, saturation parameters, transformer data, active

and reactive power, the characteristics of excitation and governor equipment, prime mover data and

data power system stabilizer.

b. PSD Installation Data

This section covers the installation of PSD data which are connected to the distribution system such as

voltage rating, insulation coordination, current rating, transformer capacity, specifications of the

transformer, grounding, source impedance, the characteristics of the nominal load current, power

quality measurement data (flashing voltage, harmonics, the work factor ).

c. Distribution System Consumer Data

This section summarizes the distribution system consumers data, such as voltage rating at a

connection point, installed protected, the internal backup supply schemes.

d. Load Characteristics of Consumer Data

This section describes the type of load, load growth forecasts and plans for the imposition of a daily /

weekly / monthly provided by the Big Consumer.

PC 6.1. Data Update Procedure

a. PSD, PD and Consumers together provide data in accordance with the format and time set forth in

this rule.

b. PD can act actively to collect data necessary for the smooth distribution of electric power.

c. If there is a change of equipment contained in the PSD and consumers are already listed on the PD,

then the PSD and the Customer shall notify the PD no later than 1 (one) month after the change

occurs.


CHAPTER VII

SETTLEMENT CODE-(SC)

Settlement Code govern transactions between PSD-PD and PD-Consumers, to the extent not otherwise

specified in the contract approved by the Parties.

SC 1.0. Objective

The objective of this rule is to clarify procedures relating to meter reading transactions, cost calculation,

billing, payment and risk mitigation for the failure of payment of power purchase and sale transactions.

Terms of Transaction

a. Implementation of the distribution system transactions between PSD and PD and between PD and

Consumer electric bills that is embodied in the calculation of costs and power consumption of

electrical energy and other costs determined in accordance with the provisions of legislation or upon

agreement of both parties involved in the transaction.

b. In doing a transaction between PD and consumer, PD can define different forms of risk mitigation for

the failure of payment of power purchase and sale transactions.

c. PD is required to announce the distribution system quality reliability levels that include the average

number of power outages per customer and the perceived average completion time of power

outages.

d. Determination of the selling price of electricity should be guided by the Electricity Basic Tariff in

accordance with the provisions of legislation.

e. In the event that average power factor of each month is less than 0.9 lagging, so in some classes of

consumers will be charged the excess consumption of reactive power according to the applicable

tariff.

f. PD determine the comparative factor (K factor) between the time of peak load pricing and time

outside of peak load pricing in accordance with local electrical load characteristic.

g. If consumers can not meet the obligation to settle payment of electricity bills, then the PD is entitled

to temporary disconnect that is terminating the connection temporarily of electrical power supply to

consumers for a while without dismantling the measurement equipment belongs to the PD.

h. If after temporary disconnection at certain times Consumer can not settle electric bills, then the PD

will do the complete termination that is termination for onward dispatching electricity to customers

installation and PD take all the existing PD's equipment at the Customer location.

i. PD will put on a power imitator to limit the amount of power that is agreed by PD and Consumers in a

power purchase agreement.

j. For the purposes of regulating the use of electricity, PD can and is entitled to perform inspection to

the installation of PD's mounted in a location owned by the Customer to be supplied from the

distribution network owned by PD.


SC 3.0. Readings and Payment

SC 3.1. Reading of Transactions

SC 3.1. I. Transactions readings between Grid with PD

Reading of the transaction between the Grid with PD is regulated in Network Code.

SC 3.1.2. Transactions readings between PSKM with PD

a. Transactions Meters between PSKM and PD is read at 10:00 the first day of each month and put into

the Minutes of Meters Reading. If there is no dispute about the data that is read, then PSKM publish

the Minutes of Electricity Transaction no later than 15 (fifteen) working days after receiving the

Minutes of Meters Reading.

b. If the transaction meter data is incomplete or contained errors then meter data comparator must be

used. If the meter data comparison is not complete or there are errors, PD uses a viable method to

make estimates that can be agreed upon.

SC 3.1.3 Reading Transactions PD with PD

a. Transactions meters between PD and PD is read at 10:00 the first day of each month and put into the

Minutes of Meters Reading. If there is no dispute about the data that is read, then the owner of the

PD distribution network assets deliver electricity to other PD publish the Minutes of Electricity

Transaction no later than 15 (fifteen) working days after receiving the Minutes of Meters Reading.

b. If the transaction meter data is incomplete or contained errors, the owner of the PD distribution

network assets that dispatch electricity using a viable method to make estimates that can be agreed

upon.

SC 3.1.4 Reading PD Transactions with Consumers and Resellers with Consumers

Transaction Meter is read every 1 (one) month or as PD/Reseller determination. If the transaction meter

data is incomplete or contained errors, PD/Reseller using appropriate methods to make estimates that

can be agreed upon.

SC 3.2. Costs of Transaction

SC 3.2.1 Costs that is charged by PD to Consumers

In managing the distribution system PD may charge a fee to the Customer in accordance with the

provisions of the legislation.

SC 3.2.2. Consumer payment to the PD

Schedule, location and manner of payment is governed by the PD based on the agreement or provision of

the contract.

SC 3.3. Sanctions of Failure to Pay

Sanctions will be given to consumers in case of late payment, or does not refill the customer deposit, in

accordance with the power purchase agreement.


SC 4.0. Transactions Dispute Settlement

SC 4.1. Transaction Dispute Settlement between PSD and PD

SC 4.1.1 Transactions Dispute Settlement between Grid and PD

Settlement of transactions disputes between Grid with PD is regulated in Network Code.

SC 4.1.2 Transactions Dispute Settlement between PSKM and PD

Copies of meter readings, time of transaction and other information used for the determination of billing

and payments can be given to the Parties that require on request. If there is any questions or corrections

suggestions of the Parties to the above data, then the question or corrections suggestions is submitted in

writing.

Transaction Dispute settlement process are as follows:

a. The Parties shall endeavor to resolve this issue through informal efforts either through a telephone

conversation or through meetings at the time and place mutually agreed;

b. if the informal efforts to resolve disputes of this transaction is not successful, the Parties in dispute to

prepare a written document of the dispute to then be submitted to KMAD. Furthermore KMAD trying

to resolve the dispute;

c. if not an agreement on the settlement of disputes, the parties who wish to pursue the issue at a

higher level may submit the matter to the arbitration body or court;

d. unless already regulated separately by the contract, if the contract between PSKM and PD contained

provisions governing transactions dispute settlement that occur, then the dispute is resolved by

reference to the provisions in the contract;

e. during the dispute resolution process, PSKM must not disconnect the electric power unilaterally until

a final decision of the National Arbitration.

SC 4.2. Settlement of Transactions Disputes between PD and Consumer

In the event of a dispute the transaction, then the published accounts must be paid in advance by the

Customer. Further agreements are expected to be achieved by both parties. If no agreement then it can

be achieved through legal channels.

SC 5.0. Settlement Process Audit Procedures

The parties have the right to request an audit for the settlement process associated with the following

conditions:

a. the parties may appoint a third party qualified to conduct the audit;

b. all costs incurred audit is the responsibility of requesting party for the audit;

c. audit results should be sent to the party being audited. Furthermore, the audited party is obligated to

provide answers to these audit results.


CHAPTER Vlll

METERING CODE-(MC)

Metering Codes describe the minimum technical and operational requirements for the meter transactions

that must be installed by the PD and PSD at the connection point of distribution.

MC 1.0. Objective

The objective of the Metering Codes is to:

a. make metering requirements of the active energy and reactive energy from and / or to the

distribution system;

b. ensure the suitability of equipment and procedures to provide metering data used in the settlement

and payment.

MC 2.0. Metering criteria

MC 2.1. Metering magnitudes

Metering of energy transactions can be done by direct or indirect methods through instrument

transformer (current transformer and voltage transformer). The quantities measured are as follows:

a. Kwh;

b. kVARh;

c. maximum kVA.

MC 2.2. Metering Accuracy

Each component metering instruments must meet the standards of accuracy at least as or better as

follows:

a. transformers instrument

Voltage transformer and current transformer to the transaction with the big consumer at the point of

connection of high voltage following the networks Codes. Voltage transformer and current

transformer for the transaction at a medium voltage connection point must have a 0.5 class accuracy.

Current transformer to the transaction at a connection point must have a Low Voltage accuracy class

1.0

b. Kilo Watt-hour Meter (kwhmeter)

1) 3 phase Connection

Meters for the transaction with the Big Consumer at the point of connection of high voltage

following the networks Codes. Meters for the transaction at a connection point has a medium

voltage accuracy class 0.5 of this type of electronic meters.

Meters for the transaction at the point of connection of low voltage, indirect metering using the

class 1.0 accuracy of this type of electronic meters, while for the direct metering using a class

accuracy of 1.0 from the electromechanical or electronic meters type. Each meter Kwh 3 phase 4

wire electronic meter of this type must have a registration export and import in accordance with

the requirements including peak load time (WBP) and outside peak load time (LWBP).


2) Connection 1 phase

Every Kwh meter must be of the type 1 phase 2 wire, having accuracy class 2.0, the type of

electromechanical or electronic meters.

c. KiloVAr-hour meter (kVArhmeter)

Each kVArh meter must be of type 3 phase 4 wire, having export registration and / or import, accuracy

class 2,0 of the type of electromechanical or electronic meters.

d. Maximum kVA demand meters

Every-maximum kVA demand meters shall be of three types of flow elements, multiple tariff, which

has a solid-state registration, accuracy class 0.5 of electromechanical or electronic type meter.

For those who still use the meter Kwh 3 phase 3 wire type can still be used but not developed anymore.

MC 2.3. Burden instrument Transformer

For indirect metering, burden instrument transformer that are used to be in the range between 25% to

100% of its rating.

MC 3.0. Meter Equipment Requirements

MC 3.1. lnstallation requirements

a. All transactions meter for Consumers should be installed at a connection point. Meters are provided

by the seller of electric power.

b. Transactions between the PD meter with PSD meters can be fitted with comparison meter.

c. adequate cupboard (cubicles / box) should be provided for meters at each connection point.

Construction to meet SNI or PD Standard (e.g.: SPLN), with prior approval of the PD. Must have a

meter cupboard doors which can be locked and sealed by the seller of electric power.

d. The diameter of the circuit voltage transformer cable must ensure the voltage drop should be less

than 1%.

e. current transformer secondary circuit and voltage transformer must be directly connected to the

meters terminal.

MC 3.2. ownership

main meters are mounted / installed and owned by the seller of electric power, while the comparison

meters may be held / mounted and owned by the purchaser of electric power with the same class. Each

party is obliged to operate and maintain the meter.

MC 4.0. Commissioning


MC 4.1. Metering Equipment Document

Especially for a PSD connection point or Big Consumers should be equipped with measuring equipment

documents as follows:

a. single-line diagram showing the connection point to the meter equipment;

b. initial testing and calibration certificate of the current transformer, voltage transformer and meter,

prepared by the seller of electric energy;

c. calculation of voltage drop on the circuit voltage provided by the electric power seller; and

d. burden calculations on the circuit meter prepared by the seller of electric power.

For any connection point that has been in operation before the Distribution Codes is enacted the above

documents is gradually completed.

MC 4.2. Installation and Testing

Installation and testing of metering equipment will be made by the seller of electric power witnessed by

the purchaser of power.

MC 4.3. test results

The results of the testing and inspection should be included in the minutes signed by the Parties.

MC 5.0. Tests After commissioning

MC 5.1. Repeat testing

Metering system is inspected and retested as needed or on request.

MC 5.2. cost of Testing

Payment of the testing set as follows:

a. if the initial test results indicate that the meter is in accordance with the standards of its class, the

requesting party pay the costs of testing; or

b. if the initial test results indicate that the meter will require recalibration, then the meter owner who

pays the costs.

MC 6.0. Sealing and Reprogramming

After the implementation of re-commissioning or re-testing of metering equipment, the PD must

immediately attach seal with clear identification. If this activity lead to changes in seal tera then sealing

seals tera be implemented by the Agency for Metrology.

Termination of seal by a party must be witnessed by other parties as outlined in the minutes.

MC 7.0. Examination of Meter Data and Equipment

MC 7.1. Rights of Access to Meter Data

The energy buyer can find out the metering data via the display / registers that exist at the meter.


MC 7.2. Rights of Access to Metering Equipment

The Energy Seller reserves the right to access directly to the metering equipment at a connection point of

distribution for purposes of inspection and testing, verification of data, read registers, seal checks, control

of electricity usage, and other things necessary.

Buyers of energy is not justified in conducting certain activities that may affect the operation of a meter

either directly or indirectly to the metering equipment at a connection point.

MC 8.0. Metering Equipment Security

MC 8.1. Changes in Metering Equipment

All changes made to the metering equipment by the seller must be witnessed by the buyer and a minutes

must be made and signed together.

MC 8.2. Changes in Metering Data

Changes to the original data stored in a meter is not allowed, and if there are errors of metering then

recalibration must be performed.

MC 9.0. Exceptions and Deadline

To kWhmeter who do not meet the provisions of MC 2.2. point b to be given a time limit of 5 (five) years

to adjust, as of the enactment of Distribution Code.

MC 10.0. Other provisions - Other

Anything else that is operational techniques in detail is not provided for in Metering Code These Metering

Code will be further elaborated by KMAD in permanent operation and maintenance procedures of

metering equipment.


GLOSSARY

This glossary defines terms used in the Distribution Codes. The consistent use of these definitions will reduce the

possibility of misunderstanding the provisions of the Codes of Distribution. In the case that a term or word expressed

specifically in a part of the Codes of Distribution, then the statement of the distribution Codes was preferred

compared with the explanations in this Glossary.

The words and the following statements which are used in Distribution Code are defined as follows:

1. ANSI: American National Standards Institute.

2. APP: Metering Equipment and barrier.

3. Short circuit current: The current that occurs due to an interruption 3 phase, 2 phase, ground

-phase.

4. Network Codes: Collection of regulations and technical and operational standards to

ensure reliable operation, safe and efficient.

5. peaks Load: the highest load in a certain time interval

6. Captive Power: The power plant used for its own sake, or private.

7. Active Power: Generation, distribution or use of electrical power, as a result of

multiplying the voltage by a phase component of alternating current,

which is usually expressed in kilowatts (kW) or Megawatts (MW). This is

part of VA or kVA of apparent power that can be transformed into light,

physical motion or heat.

8. Reactive Power: The portion of the electrical power generating and maintaining

electric/magnetic field of an alternating current equipment. Reactive

power must be supplied to the magnetic equipment such as motors and

transformers, and must be supplied to compensate for reactive losses

on transmission facilities. Expressed in kilo quantities Var (kVAR) or

MegaVAr (MVAr).

9. Voltage Depression of Short Circuit: The ratio between the short circuit electric arc furnace with a network

of short circuit power at the connection point at minimum generating

conditions.

10. Harmonic Distortion: Harmonic distortion caused by non-linear characteristics of the

provision of electric power equipment.

11. Active Energy: Magnitude of active power distribution in a period of time, usually

measured in Watt-hours (Wh) or kilowatt-hours (Kwh).

12. Reactive energy Magnitude of reactive power distribution within a period of time,

usually measured in VARhours (VARh) or kiloVAR-hours (kVARh).

13. Power Factor The ratio between active power and complex power.

14. flicker Small changes cascade voltage and continuous that can be detected by

the human eye.

15. Voltage fluctuations: Changes or voltage deviation caused by load changes.

16. Frequency distribution system Frequency in cycles per second (Hz).

17. interruption Unplanned events that resulted in an abnormal condition in the


18. substations Part of Grid which are connected directly to the distribution system and

is a supplier of electric power distribution systems demands.


19. Grid interconnection networks which can consist of a voltage 70 kV (which

became part of the transmission system), 150 kV, 275 kV and 500 kV

together with substations and other equipment.

20. Harmonic sinusoidal wave voltages or currents frequency magnitude is a multiple

of the basic frequency.

21. IEC The International Electrotechnical Commission.

22. IEEE Institute of Electrical and Electronic Engineers.

23. capacity power Output that can be achieved by a generating unit, transformer,

conductors or other equipment, which is expressed in MW or MVA.

24. Emergency A situation where the integrity, security or stability of the whole or part

in a state of danger and the presence of electrical outages.

25. Reliability The ability to supply power without interruption in all conditions.

26. Demand / Load Total active and reactive power has been supplied or expected to be

supplied to all customers via the Network (Grid) or the Distribution

Network, which is expressed in Megawatts and MegaVAR, within a

certain time period.

27. Blink of voltage drop voltage RMS (root mean square) in fractions of milliseconds to

several seconds.

28. Important Incident Serious incident affecting the distribution system reliability and

customer convenience that resulted in widespread power outages and

the restoration of electrical distribution system takes more than 3x24

hours.

29. commissioning A series of activities of inspection and testing of an installation of

provision and utilization of electric power supply to ensure the

installation is working properly and operation worthy.

30. Normal Operations of Network Condition Operating conditions on the configuration that should be and no

outages.

31. Consumers Users of electricity connected to distribution systems that are bound in

a contract with PD.

32. Big Consumers consumers with power connected greater than 1 MVA or regulated by

the PD.

33. Special Report The written report in addition to the Annual Report and the Report of

Important Incidents.

34. Load Shedding the intentional load reduction (automatic or manual) with the

termination of certain load because the incidence of shortages of

electric power supply, to maintain integrity and avoid greater network

outages.

35. Meter Apparatus for measuring electrical magnitude such as: real energy

(kWh), reactive energy (kVARh) and maximum power (kVA max) that is

used as a point of transaction.

36. NEMA National Electrical Manufacturers Association (USA).

37. All parties The Parties consist of the PSD, PD and Consumers.

38. PD Distribution Operator, State-owned enterprises designated as the power

holder or holders of electrification business or IUKU that manages the

distribution system (including network systems and facilities owned by

resellers such as operator of market, malls, apartments, etc.).


39. PDKB work in a state-voltage by using a special procedure and a set of special safety

equipment and work is generally done for maintenance and new installation of

medium voltage overhead networks with the aim of reducing the number of

outages that consumers perceived.

40. energy buyers the parties who purchase electric power.

41. Power Circuit Breaker Power breaker to close and open the electrical circuit in a state not loaded or

loaded, with a certain ability to break the short circuit current.

42. disconnection Separation of the electrical of equipment from the distribution system.

43. energy sellers Party who sells electric power.

44. grounding electrical connection between one or more conductors to the ground, which is

necessary for the safety of personnel, general and equipment safety.

45. feeders main Distribution Network at substation or connection substation.

46. Metering Equipment All equipment connected to the metering system that includes: current

transformers, voltage transformers, metering instruments.

47. Protection equipment safety equipment that serves to prevent greater damage to electrical equipment

and widespread disruption.

48. PSD Distribution System Suppliers, consisting of Grid and PSK.

49. PSKM Small and Medium Scale Generating plant directly connected to the distribution

system.

50. resellers Parties who buy electric power from the PD and resell to end consumers.

51. SCADA "Supervisory Control And Data Acquisition System", long distance control and

metering systems used to remotely monitor and control the Electric Power

System.

52. Operation acceptance certificate (SLO) Certificate which is issued by an accredited institution as the basis for the

operation of electrical equipment.

53. Settlement Activities associated with the reading and payments on the sale and purchase

transactions and settlement of disputes.

54. knot The point at which of one or more distribution networks in substation or

connection substation.

55. Distribution System network systems and related facilities owned by the licensee as PD, from a

connection point between the Grid and the PD, or PSK and PD, up to the final

consumer. (Including network systems and facilities owned by the bulk buyers

such as operator of market, malls, apartments, etc. that sell back electricity to

final consumers).

56. SNI Indonesia National Standard.

57. SOP Standard Operation Procedure, standard operating procedures to be mutually

agreed.

58. SPLN Technical Standards of PLN.

59. Electricity Basic Tariff selling price of electricity set by the Government.

60. Meter Terminals Terminal in kwhmeter.

61. Connection point The place where there is a connection between power lines PD, PSD and

Consumers.

62. UFR Under Frequency Relay, the relay that will work if there is a frequency lower

than the setting.

63. UGB Moving Substation Unit, is the distribution substations (20 kVl400V) which

moveable used to reduce the occurrence of Consumers blackouts due to work in

the distribution network.

64. Under Voltage Relay Relay that will work if the voltage is lower than the setting.

65. Generating Unit: A combination of first movers and generators (and other equipment) that

generate electric power of alternating current

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