Philippine Distribution Code 2017 Edition PDF

CHAPTER 5 DISTRIBUTION PLANNING 5.1 PURPOSE (a) To specify the responsibilities of the Distribution Utilities and the Users of the Distribution System in planning the development of the Distribution System; (b) To specify the technical studies and planning procedures that will ensure the safety and Reliability of the Distribution System; (c) To specify the planning data required for a User seeking a new connection or a modification of an existing connection to the Distribution System; and (d) To specify the data requirements to be used by the Distribution Utilities in planning the development of the Distribution System. 5.2 DISTRIBUTION PLANNING RESPONSIBILITIES AND PROCEDURES 5.2.1 Distribution Planning Responsibilities 5.2.1.1 The Distribution Utility shall be responsible for Distribution Planning, including: (a) Analyzing the impact of the connection of new facilities such as Embedded Generating Plants, Loads, distribution lines, or substations; (b) Planning the expansion of the Distribution System to ensure its adequacy to meet forecasted Demand and the connection of new Embedded Generating Plants; and (c) Identifying and correcting problems on Power Quality, System Loss, and Reliability in the Distribution System. 5.2.1.2 The Users of the Distribution System, including Embedded Generation Companies, Large Customers, and other entities that have a System connected to the Distribution System shall cooperate with the Distribution Utility in maintaining a Distribution Planning data. 5.2.2 Submission of Planning Data 5.2.2.1 As required by the Distribution Utility, a User applying for connection or a modification of an existing connection to the Distribution System shall submit to the Distribution Utility the relevant Standard Planning Data specified in Article 5.4 and the Detailed Planning Data specified in Article 5.5, in accordance with the requirements prescribed in Article 4.3. 5.2.2.2 As required by the Distribution Utility, a User shall submit annually to the Distribution Utility the relevant historical planning data for the previous year and the forecast planning data for the five succeeding years by calendar week 23 of the current year. These shall include the updated Standard Planning Data and the Detailed Planning Data. December 2017 79 Philippine Distribution Code 2017 Edition Distribution Planning 5.2.2.3 The required Standard Planning Data specified in Article 5.4 shall consist of information necessary for the Distribution Utility to evaluate the impact of any User Development on the Distribution System. 5.2.2.4 The Detailed Planning Data specified in Article 5.5 shall include additional information necessary for the conduct of a more accurate Distribution Planning study. This shall cover circuit parameters, switchgear, and protection arrangements of equipment directly connected to or affecting the Distribution System. The data shall be adequate to enable the Distribution Utility to assess any implication associated with the Connection Points. 5.2.2.5 The Standard Planning Data and Detailed Planning Data shall be submitted by the User to the Distribution Utility according to the following categories: (a) Forecast Data; (b) Estimated Equipment Data; and (c) Registered Equipment Data. 5.2.2.6 The Forecast Data shall contain the User’s best estimate of the data, including Energy and Demand, being projected for the five succeeding years. 5.2.2.7 The Estimated Equipment Data shall contain the User’s best estimate of the values of parameters and information pertaining to its Equipment. 5.2.2.8 The Registered Equipment Data shall contain validated actual values of parameters and information about the User’s Equipment, which are part of the Connected Project Planning Data submitted by the User to the Distribution Utility at the time of connection. 5.2.3 Consolidation and Maintenance of Planning Data 5.2.3.1 The Distribution Utility shall consolidate and maintain the Distribution planning data according to the following categories: (a) Forecast Data; (b) Estimated Equipment Data; and (c) Registered Equipment Data. 5.2.3.2 If there is any change to its planning data, the User shall notify the Distribution Utility of the change as soon as possible. The notification shall contain the time and date when the change took effect, or is expected to take effect, as the case may be. If the change is temporary, the time and date when the data is expected to revert to its previous registered value shall also be indicated in the notification. 5.2.4 Evaluation of Proposed Development 5.2.4.1 The Distribution Utility shall conduct Distribution Impact Studies to assess the effect of the proposed User Development on the Distribution System and the System of other Users. 5.2.4.2 The Distribution Utility shall notify the User of the results of the Distribution Impact Studies. 80 December 2017 Distribution Planning Philippine Distribution Code 2017 Edition 5.2.4.3 The Distribution Utility shall also notify the User of any planned development in the Distribution System that may have an impact on the User System. 5.2.5 Preparation of Distribution Development Plan 5.2.5.1 The Distribution Utility shall collate and process the planning data submitted by the Users into a cohesive forecast and use this in preparing the data for the Distribution Development Plan (DDP). 5.2.5.2 The Distribution Utility shall develop and submit annually to the DOE a DDP. In the case of an Electric Cooperative, such plan shall be submitted to the DOE through the NEA. A copy of the DDP shall also be submitted to the ERC, through the DMC. 5.2.5.3 The Distribution Development Plan shall include: (a) Energy and Demand forecasts; (b) Sub-transmission capacity expansion; (c) Distribution substation siting and sizing; (d) Distribution feeder routing and sizing; (e) Distribution Reactive Power compensation plan; (f) Other Distribution reinforcement plans; and (g) A summary of the technical and economic analysis performed to justify the DDP. 5.2.5.4 If a User believes that the cohesive forecast prepared by the Distribution Utility does not accurately reflect its assumptions on the planning data, it shall promptly notify the Distribution Utility of its concern. The Distribution Utility and the User shall promptly meet to address the concern of the User. 5.3 DISTRIBUTION PLANNING STUDIES 5.3.1 Distribution Planning Studies 5.3.1.1 The Distribution Utility shall conduct distribution planning studies to ensure the safety and reliability of the Distribution System for the following purposes: (a) Preparation of the Distribution Development Plan to be submitted annually to DOE; (b) Evaluation of Distribution System reinforcement projects; and (c) Evaluation of any proposed User Development, which is submitted in accordance with an application for a Connection Agreement or an Amended Connection Agreement. 5.3.1.2 The distribution planning studies shall be conducted to assess the impact on the Distribution System, or to any User System of any Demand Forecast or any proposed Equipment change in the Distribution System, or the User System and to identify corrective measures to eliminate the deficiencies in the Distribution System, or the User System. December 2017 81 Philippine Distribution Code 2017 Edition Distribution Planning 5.3.1.3 The relevant technical studies described in Sections 5.3.2 to 5.3.5 and the required planning data specified in Articles 5.4 and 5.5 shall be used in the conduct of the distribution planning studies. 5.3.1.4 The Distribution Utility shall conduct distribution planning analysis which shall include: (a) The determination of optimum patterns for the selection of sites and sizes of distribution substations; (b) The determination of optimum patterns for feeder development; (c) The development of optimum Reactive Power compensation programs; and (d) The development of an optimum feeder configuration and switching controls for distribution feeders. 5.3.1.5 The distribution planning studies shall be performed using lifecycle costing methods. The cost of capital and the discount rate used in such analysis shall be prescribed by the ERC. 5.3.2 Voltage Drop Studies 5.3.2.1 Voltage drop studies shall be performed to determine the Voltages at the Connection Points for the forecasted Demand of the existing Distribution System and any planned expansion, reinforcement, or development. 5.3.2.2 Voltage drop studies shall be performed to evaluate the impact of the connection of new Embedded Generating Plants, loads, or distribution lines on the Distribution System. 5.3.3 Short Circuit Studies 5.3.3.1 Short circuit studies shall be performed to evaluate the effect on the Distribution System Equipment of the connection of new Generating Plants and other facilities that will result in increased fault duties for the Distribution System Equipment. These studies shall identify the Equipment that could be damaged when current exceeds the design limit of the Equipment. The studies shall also identify the Circuit Breakers and fuses, which may fail when interrupting possible short circuit currents. 5.3.3.2 Three-phase short-circuit studies shall be performed for all nodes of the Distribution System for the maximum and minimum generation scenarios of the Grid and for different system circuit configurations. 5.3.3.3 Single line-to-ground fault studies shall also be performed for critical Distribution System nodes. These studies shall identify the most severe conditions that the Distribution System Equipment may be exposed to. 5.3.3.4 The Distribution Utility and the User shall exchange information on fault infeed levels at the Connection Point. The information shall include: (a) The maximum and minimum three-phase and line-to-ground fault infeeds; (b) The X/R ratio under short circuit conditions; and (c) In the case of interconnected Systems, an adequate equivalent network representation for short circuit calculations. 82 December 2017 Distribution Planning Philippine Distribution Code 2017 Edition 5.3.3.5 Alternative Distribution System circuit configurations may be studied to reduce the short circuit current within the limits of existing Equipment. The results shall be considered satisfactory when the short-circuit currents are within the design limits of the Equipment and the proposed Distribution System configurations are suitable for flexible and safe operation. 5.3.4 System Loss Studies 5.3.4.1 System Loss studies shall be performed to identify, classify, and quantify the losses in the Distribution System. The various categories and components of System Loss specified in Article 3.4 shall be identified and quantified in conducting the System Loss studies. 5.3.4.2 System Loss studies shall be performed to determine the effects of any User Development and any development in the Distribution System on the efficiency of the Distribution System. 5.3.5 Distribution Reliability Studies 5.3.5.1 Distribution Reliability studies shall be performed to determine the frequency and duration of Customer Interruptions in the Distribution System. 5.3.5.2 The historical Reliability performance of the Distribution System shall be determined from the Interruptions data of the Distribution System. 5.4 STANDARD PLANNING DATA 5.4.1 Energy and Demand Forecast 5.4.1.1 The User shall provide the Distribution Utility with its Energy and Demand forecasts at each Connection Point for the five succeeding years. 5.4.1.2 The Forecast Data for the first year shall include monthly Energy and Demand forecasts, while the remaining four years shall include only the annual Energy and Demand forecasts. 5.4.1.3 The Users shall provide the net values of Energy and Demand forecast after any deductions to reflect the output of a Customer Self-Generating Plant. Such deductions shall be stated separately in the Forecast Data. 5.4.1.4 The following factors shall be taken into account by the Distribution Utility and the User when forecasting Demand: (a) Historical Demand data; (b) Demand trends; (c) Significant public events; (d) Customer Self-Generating Plant schedules; (e) Demand transfers; (f) Interconnection with adjacent Distribution Utilities; and (g) Other relevant factors. 5.4.1.5 The Large Conventional, Large VRE, Medium, Intermediate Embedded Generation Companies and, if required, End-Users using Small Embedded Generating Plants shall submit to the Distribution Utility the December 2017 83 Philippine Distribution Code 2017 Edition Distribution Planning projected capability to be generated on an hourly basis by each Generating Unit or Generating Plant. 5.4.2 Embedded Generating Unit Data 5.4.2.1 The Embedded Generation Company shall provide the Distribution Utility with data relating to the Embedded Generating Units. 5.4.2.2 The Embedded Generation Company shall provide the Distribution Utility the following information about its Generating Unit or Generating Plant: (a) Rated Capacity (MVA and MW); (b) Rated Voltage (kV); (c) Type of Generating Unit and expected running mode(s); (d) Direct axis subtransient reactance (%); and (e) Rated capacity, voltage, and impedance of the Generating Unit’s step- up Transformer. 5.4.2.3 The following information shall be provided by the Embedded Generation Company for their Wind Generating Plant: (a) Name and location of the Wind Farm; (b) Wind Farm capacity; (c) Total VRE Installed Capacity; (d) Number of units and unit size; (e) Type of wind turbines used in the Wind Farm (fixed speed/variable speed); (f) Wind turbine Manufacturer; (g) Rated power of each wind turbine (kW); (h) Rated Apparent Power (kVA); (i) Rated Frequency (Hz); (j) Rated wind speed (m/s); (k) Cut-in wind speed (m/s); (l) Cut-off wind speed (m/s); and (m) Rated Voltage (V). 5.4.2.4 The following information shall be provided by the Embedded Generation Company for their PVSs: (a) Name and location of the PVS Generating Unit; (b) Total Installed Capacity (kWp); (c) Number of units and unit size; (d) Inverter Power Rating (kW); (e) Inverter Manufacturer and Model; (f) Solar Panel Technology; (g) PVS Transformer data, if applicable; (h) Transformer Voltage Ratio, if applicable; (i) Percentage Impedance, if applicable; (j) Winding Connection, if applicable; and 84 December 2017 Distribution Planning Philippine Distribution Code 2017 Edition (k) Tap Settings, if applicable. 5.4.2.5 If the Embedded Generating Unit is connected to the Distribution System at a Connection Point with a bus arrangement which is, or may be operated in separate sections, the bus section to which each Generating Unit is connected shall be identified. 5.4.3 User System Data 5.4.3.1 If the User is to be connected at LV, the following data shall be provided to the Distribution Utility: (a) Connected Loads; and (b) Maximum Demand. 5.4.3.2 If the User is to be connected at MV or HV, the following data shall be provided to the Distribution Utility: (a) All types of Loads: (1) Connected Load, including type and control arrangements; (2) Maximum Demand; (b) Fluctuating and Cyclical Loads: (1) The rate of change of the Demand; (2) The switching interval; and (3) The magnitude of the largest step change. 5.4.3.3 The User shall provide the Electrical Diagrams and Connection Point Drawings of the User System and the Connection Point, as specified in Articles 4.12 and 4.13, respectively. The diagrams and drawings shall indicate the quantities, ratings, and operating parameters of the following: (a) Equipment (e.g., Generating Unit, power Transformer, and Circuit Breaker); (b) Electrical circuits (e.g., overhead lines and underground cables); (c) Substation bus arrangements; (d) Grounding arrangements; (e) Phasing arrangements; and (f) Switching facilities. 5.4.3.4 The User shall provide the values of the following circuit parameters of the overhead lines and/or underground cables from the User’s substation to the Connection Point in the Distribution System: (a) Rated and operating Voltage (kV); (b) Positive sequence resistance and reactance (ohm); (c) Positive sequence shunt susceptance (Siemens or ohm-1); (d) Zero sequence resistance and reactance (ohm); and (e) Zero sequence susceptance (Siemens or ohm-1). 5.4.3.5 If the User System is connected to the Distribution System through a step-up Transformer, the following data for the power Transformers shall be provided: (a) Rated MVA; December 2017 85 Philippine Distribution Code 2017 Edition Distribution Planning (b) Rated Voltages (kV); (c) Winding arrangement; (d) Positive sequence resistance and reactance (at max, min, and nominal tap); (e) Zero sequence reactance for three-legged core type Transformer; (f) Tap changer range, step size and type (on-load or off-load); and (g) Basic Lightning Impulse Insulation Level (kV). 5.4.3.6 The User shall provide the following information for the switchgear, including Circuit Breakers, Load break switches, and disconnect switches at the Connection Point and at the substation of the User: (a) Rated Voltage (kV); (b) Rated current (A); (c) Rated symmetrical RMS short-circuit current (kA); and (d) Basic Lightning Impulse Insulation Level (kV). 5.4.3.7 The User shall provide the details of its System Grounding. This shall include the rated capacity and impedances of the Grounding Equipment. 5.4.3.8 The User shall provide the data on independently-switched Reactive Power compensation Equipment at the Connection Point and at the substation of the User. This shall include the following information: (a) Rated Capacity (MVAR); (b) Rated Voltage (kV); (c) Type (e.g., shunt inductor, shunt capacitor, static var compensator); and (d) Operation and control details (e.g., fixed or variable, automatic, or manual). 5.4.3.9 If a significant portion of the User’s Demand may be supplied from an alternative Connection Point, the relevant information on the Demand transfer capability shall be provided by the User including the following: (a) The alternative Connection Point; (b) The Demand normally supplied from each alternative Connection Point; (c) The Demand which may be transferred from or to each alternative Connection Point; and (d) The control (e.g., manual or automatic) arrangements for transfer including the time required to effect the transfer for Forced Outage and planned maintenance conditions. 5.4.3.10 If the User has an Embedded Generating Plants and/or significantly large motors, the short circuit contributions of the Generating Units and the large motors at the Connection Point shall be provided by the User. The short circuit current shall be calculated in accordance with the international standards (e.g., ANSI/IEEE, IEC). 86 December 2017 Distribution Planning Philippine Distribution Code 2017 Edition 5.5 DETAILED PLANNING DATA 5.5.1 Embedded Generating Unit Data 5.5.1.1 All Conventional Embedded Generation Company shall provide the Distribution Utility the following additional information for its Generating Unit or Generating Plant: (a) Derated Capacity (MW) on a monthly basis, if applicable; (b) Additional capacity (MW) obtainable from Generating Units in excess of Net Declared Capacity; (c) Minimum Stable Loading (MW); (d) Reactive Power Capability Curve; (e) Stator armature resistance; (f) Direct axis synchronous, transient, and subtransient reactances; (g) Quadrature axis synchronous, transient, and subtransient reactances; (h) Direct axis transient and subtransient time constants; (i) Quadrature axis transient and subtransient time constants; (j) Turbine and Generating Unit inertia constant (MWsec/MVA); (k) Rated field current (A) at rated MW and MVAR output and at rated terminal Voltage; and (l) Short circuit and open circuit characteristic curves. 5.5.1.2 The following information shall be provided by the Embedded Generation Company for their Wind Generating Plant: (a) Dynamic model of the Wind Farm. In case the Wind Turbine Generating Units in the Wind Farm are not identical, the model shall incorporate separate modules to represent each type of Wind Turbine Generating Unit. Appropriate data and parameter values must be provided for each model. The dynamic model must represent the features and phenomena likely to be relevant to angular and Voltage Stability, such as Generating Plant model, blade pitch control, model of drive train and model of converter, if any; (b) Reactive compensation. Provide the details of reactive compensation, operating Power Factor range; (c) Wind Turbine Transformer data; (d) Transformer Voltage ratio; (e) Transformer data; (f) Percentage impedance; (g) Voltage ratio; (h) Winding connection; and (i) Tap settings. 5.5.1.3 The following information shall be provided by the Embedded Generation Company for their PVSs: (a) Solar Panel Data; (b) Solar Panel Manufacturer; (c) Rated Power per Solar Panel (kW); December 2017 87 Philippine Distribution Code 2017 Edition Distribution Planning (d) Solar Panel Generating Unit Technology; (e) Rated Apparent Power (kVA); (f) Frequency Tolerance Range (Hz); (g) Width (mm); (h) Height (mm); (i) Area (m2); (j) Rated Voltage (Volt); (k) Rated Current (A); (l) Watts per square meter; (m) Efficiency (%); (n) Dynamic model of the PVS: Provide a dynamic model compatible with standard dynamic simulation tools; (o) Reactive compensation: Provide details of reactive compensation and operating Power Factor range; and (p) PVS Configuration: Single line diagram of connection scheme and details of the conductor used. 5.5.1.4 The Embedded Generation Company shall provide the Distribution Utility the following information on Step-up Transformers for its Generating Unit or Generating Plant: (a) Rated MVA; (b) Rated Frequency (Hz); (c) Rated Voltage (kV); (d) Power Factor; (e) Voltage ratio; (f) Positive sequence reactance (maximum, minimum, and nominal tap); (g) Positive sequence resistance (maximum, minimum, and nominal tap); (h) Zero sequence reactance; (i) Tap changer range; (j) Tap changer step size; and (k) Tap changer type: on load or off circuit. 5.5.1.5 The Conventional or VRE Embedded Generation Company shall provide the Distribution Utility the following excitation control system parameters for its Generating Unit or Generating Plant: (a) DC gain of Excitation Loop; (b) Rated field Voltage; (c) Maximum field Voltage; (d) Minimum field Voltage; (e) Maximum rate of change of field Voltage (rising); (f) Maximum rate of change of field Voltage (falling); (g) Details of Excitation Loop described in diagram form showing transfer functions of individual elements; (h) Dynamic characteristics of overexcitation limiter; and 88 December 2017 Distribution Planning Philippine Distribution Code 2017 Edition (i) Dynamic characteristics of underexcitation limiter. 5.5.1.6 All Conventional Embedded Generation Company shall provide the Distribution Utility the following speed-governing parameters for reheat steam Generating Units or Generating Plants: (a) High pressure governor average gain (MW/Hz); (b) Speeder motor setting range; (c) Speed droop characteristic curve; (d) High pressure governor valve time constant; (e) High pressure governor valve opening limits; (f) High pressure governor valve rate limits; (g) Reheater time constant (Active Energy stored in reheater); (h) Intermediate pressure governor average gain (MW/Hz); (i) Intermediate pressure governor setting range; (j) Intermediate pressure governor valve time constant; (k) Intermediate pressure governor valve opening limits; (l) Intermediate pressure governor valve rate limits; (m) Details of acceleration sensitive elements in high pressure and intermediate pressure governor loop; and (n) A governor block diagram showing the transfer functions of individual elements. 5.5.1.7 All Conventional Embedded Generation Company shall provide the Distribution Utility the following speed-governing parameters for non- reheat steam, gas turbine, geothermal, and hydro Generating Units or Generating Plants: (a) Governor average gain; (b) Speeder motor setting range; (c) Speed droop characteristic curve; (d) Time constant of steam or fuel governor valve or water column inertia; (e) Governor valve opening limits; (f) Governor valve rate limits; and (g) Time constant of turbine. 5.5.1.8 The Embedded Generation Company shall provide the Distribution Utility the following plant flexibility performance data for its Generating Unit or Generating Plant: (a) Rate of loading following weekend Shutdown (Generating Unit and Generating Plant); (b) Rate of loading following an overnight Shutdown (Generating Unit and Generating Plant); (c) Block Load following synchronizing; (d) Rate of Load Reduction from normal rated MW; (e) Regulating range; and (f) Load rejection capability while still Synchronized and able to supply load. December 2017 89 Philippine Distribution Code 2017 Edition Distribution Planning 5.5.1.9 The Embedded Generation Company shall provide the Distribution Utility the following auxiliary Demand data for its Generating Unit or Generating Plant: (a) Normal unit-supplied auxiliary Load for each Generating Unit at rated MW output; and (b) Each Generating Plant auxiliary Load other than (a) above and where the station auxiliary Load is supplied from the Distribution System. 5.5.2 User System Data 5.5.2.1 Large Customers and other Users connected to the Distribution System shall submit to the Distribution Utility the following Load characteristics: (a) Maximum Demand on each phase at peak load condition; (b) The Voltage Unbalance; and (c) The harmonic content. 5.5.2.2 The Distribution Utility and the User shall exchange information, including details of physical and electrical layouts, parameters, specifications, and protection, needed to conduct an assessment of transient Overvoltage effects in the Distribution System or the User System. 5.5.2.3 The User shall provide any additional planning data that may be requested by the Distribution Utility. 90 December 2017 CHAPTER 6 DISTRIBUTION OPERATIONS 6.1 PURPOSE (a) To define the operational responsibilities of the Distribution Utilities and all Users of the Distribution System; (b) To specify the operational arrangements for mutual assistance, Equipment and inventory sharing, and joint purchases among Distribution Utilities; (c) To specify the requirements for communication and the notices to be issued by the Distribution Utility to Users and the notices to be issued by Users to the Distribution Utility and other Users. (d) To specify the Maintenance Programs for the Equipment and facilities in the Distribution System; (e) To describe the Demand Control strategies used for the control of the System Frequency and the methods used for Voltage Control; (f) To specify the procedures to be followed by the Distribution Utility and Users during emergency conditions; (g) To specify the procedures for the coordination, establishment, maintenance, and cancellation of Safety Precautions when work or testing other than System Test is to be carried out on the Distribution System or the User System; (h) To specify the procedures for testing and monitoring the quality of power supplied to the Distribution System and the User System; (i) To establish a procedure for the conduct of System Tests which involve the simulation of conditions or the controlled application of unusual or extreme conditions that may have an impact on the Distribution System or the User System; (j) To identify the tests and the procedures that need to be carried out to confirm the compliance of an Embedded Generating Unit with its registered parameters and its ability to provide Ancillary Services; and (k) To specify the requirements for Site and Equipment Identification at the Connection Point. 6.2 OPERATIONAL RESPONSIBILITIES 6.2.1 Operational Responsibilities of the Distribution Utility 6.2.1.1 The Distribution Utility shall be responsible for operating and maintaining Power Quality in the Distribution System during normal conditions, in accordance with the provision of Article 3.2, and in proposing solutions to Power Quality problems. 6.2.1.2 The Distribution Utility is responsible for preparing the Distribution Maintenance Program for the maintenance of its Equipment and facilities. 6.2.1.3 The Distribution Utility is responsible for providing and maintaining all Distribution Equipment and facilities. December 2017 91 Philippine Distribution Code 2017 Edition Distribution Operations 6.2.1.4 The Distribution Utility is responsible for designing, installing, and maintaining a distribution protection system that will ensure the timely disconnection of faulted facilities and Equipment. 6.2.1.5 The Distribution Utility is responsible for ensuring that safe and economic distribution operating procedures are complied with. 6.2.1.6 The Distribution Utility is responsible for maintaining an Automatic Load Dropping scheme, as necessary, to meet the targets agreed upon with the System Operator. 6.2.1.7 The Distribution Utility is responsible for developing and proposing Distribution Wheeling Charges to the ERC. 6.2.2 Operational Responsibilities of Embedded Generation Companies 6.2.2.1 The Embedded Generation Company is responsible for ensuring that its Generating Units can deliver the capabilities declared in its Connection Agreement or Amended Connection Agreement. 6.2.2.2 The Embedded Generation Company is responsible for providing accurate and timely planning and operations data to the Distribution Utility. 6.2.2.3 The Embedded Generation Company is responsible for executing the instructions of the Distribution Utility during Normal, Alert or Emergency conditions. 6.2.2.4 The Embedded Generation Company shall be responsible for ensuring that its Generating Units will not disconnect from the Distribution System during disturbances except when: (a) The Frequency or Voltage Variation would damage the Equipment of the Generation Company; or (b) The Frequency or Voltage Variation is outside the prescriptions contained in Chapter 4; or (c) When the Distribution Utility has authorized the Generation Company to do so. 6.2.3 Operational Responsibilities of Large VRE Embedded Generation Companies 6.2.3.1 In Normal State, Large VRE Embedded Generating Plants shall be operated in the Free Active Power Production control mode (as defined in the latest edition of the Philippine Grid Code) or at any other control mode in case the Embedded Generation Company decides so. 6.2.3.2 In Alert State, the System Operator through the Distribution Utility shall make its best endeavors to permit Large VRE Embedded Generating Plants to continue operating in the Free Active Power Production control mode (as defined in the latest edition of the Philippine Grid Code). However, where necessary to maintain Security in the system, the System Operator through the Distribution Utility may instruct the Embedded Generating Plant personnel to change the Active Power control mode of their Generating Plants to any of those established in Section 4.6.5. 92 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.2.3.3 In Emergency, Extreme or Restorative States the System Operator through the Distribution Utility, or the Distribution Utility independently, shall issue appropriate instructions to Large VRE Embedded Generating Plants regarding the operation of this type of facilities. For the avoidance of doubt, these instructions may include the immediate disconnection of Large VRE Embedded Generating Plants from the network. 6.2.3.4 Large VRE Embedded Generating Plants shall permanently maintain Embedded Generating Plant personnel capable to properly execute the instructions issued by the System or Distribution Utility. 6.2.3.5 Embedded Generating Plant personnel shall promptly follow the instructions issued by the Distribution Utility or the System Operator through the Distribution Utility, implementing the actions requested in the Embedded Generating Plant control system without any intentional delay. 6.2.3.6 Any instruction issued by the System Operator to Large VRE Embedded Generation Company through the Distribution Utility implying a change in the Active Power Production control mode shall be clearly reflected in the weekly reports on Grid Operation, containing an explanation of the causes and an assessment of the performance of the Large VRE Embedded Generating Plant personnel in complying with the instructions. 6.2.4 Scheduling and Dispatch Embedded Generation Companies that intend to register or are registered in the WESM shall comply with the requirements of the Scheduling and Dispatch Chapter of the Philippine Grid Code. 6.2.5 Operational Responsibilities of Other Distribution Users 6.2.5.1 The User is responsible for assisting the Distribution Utility in maintaining Power Quality in the Distribution System during normal conditions by correcting any User facility that causes Power Quality problems. 6.2.5.2 The User shall be responsible for ensuring that its System will not cause any Degradation of the Distribution System. It shall also be responsible in undertaking all necessary measures to remedy any degradation that the User System has caused to the Distribution System. 6.2.5.3 The User is responsible for executing the instructions of the Distribution Utility during emergency conditions. 6.3 OPERATIONAL ARRANGEMENTS 6.3.1 Mutual Assistance 6.3.1.1 The DMC shall recommend emergency procedures to the Distribution Utilities, including the development of a mutual assistance program for Distribution Utilities. 6.3.1.2 The Distribution Utilities shall cooperate in the establishment of mutual assistance procedures and in providing coordinated responses during emergencies. December 2017 93 Philippine Distribution Code 2017 Edition Distribution Operations 6.3.2 Equipment and Inventory Sharing 6.3.2.1 The DMC shall recommend procedures for Equipment and inventory sharing to the Distribution Utilities, including the development of an Equipment and inventory sharing program for Distribution Utilities. 6.3.2.2 The Distribution Utilities shall cooperate in the establishment of procedures for Equipment and inventory sharing and in the implementation of an Equipment and inventory sharing program that will minimize procurement cost. 6.3.3 Joint Purchases 6.3.3.1 The DMC shall recommend procedures for joint purchase arrangements to the Distribution Utilities, including the development of a joint purchase program for Distribution Utilities. 6.3.3.2 The Distribution Utilities shall cooperate in the establishment of procedures for the joint purchase of Equipment and in the implementation of a joint purchase program to achieve economies of scale in the procurement of Equipment and supplies. 6.4 DISTRIBUTION OPERATIONS COMMUNICATIONS, NOTICES, AND REPORTS 6.4.1 Distribution Operations Communications 6.4.1.1 The Distribution Utility and the User shall establish a communication channel for the exchange of information required for distribution and open access operation. The communication channel shall, as much as possible, be direct between the Distribution Utility and the User, and between the Distribution Utility and the Supplier. 6.4.1.2 Where it is determined by the Distribution Utility that a backup or alternative route of communication and/or emergency communication is necessary for the safe operation of the Distribution System, the Distribution Utility and the User shall agree on the additional means of communication. 6.4.1.3 The Distribution Utility and the User shall provide the other with the names and contact numbers of their respective duly authorized personnel so that control activities can be efficiently coordinated, and maintain the 24-hour availability of these personnel. 6.4.2 Distribution Operations Notices 6.4.2.1 A Significant Incident Notice shall be issued by the Distribution Utility or any User if a Significant Incident has transpired in the Distribution System or the System of the User, as the case may be; copy furnished the Supplier, if applicable. The notice shall be issued within 15 minutes from the occurrence of the Significant Incident, and shall identify the possible consequences on the Distribution System and/or the System of other Users and any initial corrective measures that were undertaken by the Distribution Utility or the User, as the case may be. 94 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.4.2.2 A Planned Activity Notice shall be issued by a User to the Distribution Utility, and if applicable, to the Supplier for any planned activity such as a planned Shutdown or Scheduled Maintenance of its Equipment at least 3 days prior to the actual Shutdown or maintenance. 6.4.3 Distribution Operations Reports 6.4.3.1 The Distribution Utility shall prepare and submit to the DMC monthly reports on distribution operation. These reports shall include an evaluation of the Events and other problems that occurred within the Distribution System for the previous month, the measures undertaken by the Distribution Utility to address them, and the recommendations to prevent their recurrence. 6.4.3.2 The Distribution Utility shall submit to the DMC the Significant Incident Reports prepared pursuant to the provisions of Section 6.7.2. 6.4.3.3 The Distribution Utility shall prepare and submit to the DMC an annual operations report. This report shall include the Significant Incidents on the Distribution System that had a Material Effect on the Distribution System or the System of any User. 6.5 DISTRIBUTION MAINTENANCE PROGRAM 6.5.1 Preparation of Maintenance Program 6.5.1.1 The Distribution Utility shall prepare the following Distribution Maintenance Programs based on forecasted Demand, User’s provisional Maintenance Program, and requests for maintenance schedule: (a) Three-Year Maintenance Program; (b) Annual Maintenance Program; and (c) Monthly Maintenance Program; 6.5.1.2 The three-year Maintenance Program shall be prepared annually for the three succeeding years. The annual Maintenance Program shall be developed based on the maintenance schedule for the first year of the three-year Maintenance Program. The monthly Maintenance Program shall provide the details required by the System Operator for the preparation of the Grid Operating Program, as specified in the Philippine Grid Code. 6.5.1.3 The Distribution Maintenance Program shall be developed taking into account the following: (a) The forecasted Demand; (b) The Maintenance Program actually implemented; (c) The requests by Users for changes in their maintenance schedules; (d) The requirements for the maintenance of the Grid; (e) The need to minimize the total cost of the required maintenance; and (f) Any other relevant factors. 6.5.2 Submission and Approval of Maintenance Program 6.5.2.1 The User shall provide the Distribution Utility by week 23 of the current year a provisional Maintenance Program for the three succeeding December 2017 95 Philippine Distribution Code 2017 Edition Distribution Operations years. The following information shall be included in the User’s provisional Maintenance Program and when the User requests for a maintenance schedule for its System or Equipment: (a) Identification of the Equipment and the MW capacity involved; (b) Reasons for the maintenance; (c) Expected duration of the maintenance work; (d) Preferred start date for the maintenance work and the date by which the work shall have been completed; and (e) If there is flexibility in dates, the earliest start date and the latest Completion Date. 6.5.2.2 The Maintenance Program submitted by the Embedded Generation Company for its Scheduled Generating Units shall be submitted by the Distribution Utility to the Transmission Network Provider by week 27 of the current year. 6.5.2.3 The Distribution Utility shall endeavor to accommodate the User’s request for maintenance schedule at particular dates in preparing the Distribution Maintenance Program. 6.5.2.4 The Distribution Utility shall provide the User a written copy of the User’s approved Maintenance Program. 6.5.2.5 If the User is not satisfied with the Maintenance Schedule allocated to its Equipment, it shall notify the Distribution Utility to explain its concern and to propose changes in the Maintenance Program. The Distribution Utility and the User shall discuss and resolve the problem. The Maintenance Program shall be revised by the Distribution Utility based on the resolution of the User’s concerns. 6.6 DEMAND AND VOLTAGE CONTROL 6.6.1 Demand Control Coordination 6.6.1.1 The Distribution Utility shall implement Demand Control when the System Operator has issued a Red Alert notice due to a generation deficiency in the Grid or when a Multiple Outage Contingency resulted in Island Grid operation. 6.6.1.2 The Demand Control to be implemented by the Distribution Utility shall include the following: (a) Automatic Load Dropping; (b) Manual Load Dropping; and (c) Voluntary Demand Management. 6.6.1.3 If the System Operator has issued an instruction to implement Demand Control for the Security of the Grid, the Distribution Utility shall promptly implement the instruction of the System Operator. 6.6.1.4 If the Demand Control is to be undertaken by the Distribution Utility to safeguard its Distribution System, the Distribution Utility shall coordinate the Demand Control with the affected Users and its Supplier, as the case may be. 96 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.6.1.5 The Distribution Utility shall abide by the instruction of the System Operator with regard to the restoration of Demand. The restoration of Demand shall be achieved as soon as possible and the process of restoration shall begin within 2 minutes after the instruction is given by the System Operator. 6.6.1.6 If a User is disconnected due to Demand Control, the User shall not reconnect its System until instructed by the Distribution Utility to do so. 6.6.2 Automatic Load Dropping 6.6.2.1 The System Operator shall establish the level of Demand required for Under-Frequency Load Shedding (UFLS) and Under-Voltage Load Shedding (UVLS) in order to limit the consequences of Significant Incidents or a major loss of generation in the Grid. The System Operator shall conduct the appropriate technical studies to justify the targets and/or to refine them as necessary. 6.6.2.2 The Distribution Utility shall prepare its UFLS program in consultation with the System Operator. The Distribution Utility’s Demand that is subject to UFLS shall be split into rotating discrete MW blocks. The System Operator shall specify the number of blocks and the underfrequency setting for each block. 6.6.2.3 If the Distribution Utility does not implement a UFLS program, the Transmission Network Provider shall install the Underfrequency Relay at the main feeder and the System Operator shall drop the User Demand as a single block, if the need arises. 6.6.2.4 To ensure that a subsequent fall in Frequency will be contained by the operation of UFLS, additional Manual Load Dropping shall be implemented by the Distribution Utility so that the loads that were dropped by UFLS can be reconnected. 6.6.2.5 If an ALD has taken place, the affected User shall not reconnect its disconnected feeder without clearance from the Distribution Utility. The Distribution Utility shall issue the order to reconnect upon instruction by the System Operator. 6.6.2.6 The Distribution Utility shall notify the System Operator of the actual Demand that was disconnected by UFLS, or the Demand that was restored in the case of reconnection, within 5 minutes of the Load dropping or reconnection. 6.6.2.7 The Distribution Utility shall notify the System Operator of the actual Demand that was disconnected by UVLS, or the Demand that was restored in the case of reconnection, within 5 minutes of the Load dropping or reconnection. 6.6.3 Manual Load Dropping 6.6.3.1 The Distribution Utility shall make arrangements that will enable it to disconnect its Customers immediately following the issuance by the System Operator of an instruction to implement MLD. December 2017 97 Philippine Distribution Code 2017 Edition Distribution Operations 6.6.3.2 Distribution Utilities shall, in consultation with the System Operator, establish a priority scheme for MLD based on equitable load allocation. 6.6.3.3 If the System Operator has determined that the MLD carried out by the User is not sufficient to contain the decline in Grid frequency, the System Operator may disconnect the total Demand of the Distribution Utility in an effort to preserve the integrity of the Grid. 6.6.3.4 If the Distribution Utility disconnected its Customers upon the instruction of the System Operator, the Distribution Utility shall not reconnect the affected Customer until instructed by the System Operator to do so. 6.6.3.5 If the Distribution Utility disconnected a User System, the User shall not reconnect its System until instructed by the Distribution Utility to do so. 6.6.4 Voluntary Demand Management 6.6.4.1 If a User intends to implement for the following day Demand Control through a Demand Disconnection at the Connection Point, it shall notify the Distribution Utility of the hourly schedule before 0830 hours of the current day. The notification shall contain the following information: (a) The proposed (in the case of prior notification) and actual (in the case of subsequent notification) date, time, and duration of implementation of the Demand Disconnection; and (b) The magnitude of the proposed reduction by the use of Demand Disconnection. The Distribution Utility shall provide the System Operator with the amount of Demand reduction actually achieved by the use of the Demand Disconnection. 6.6.4.2 If a User intends to implement for the following day Demand Control through a Customer Demand Management, it shall notify the Distribution Utility of the hourly schedule before 0830 hours of the current day. The notification shall contain the following information: (a) The proposed (in the case of prior notification) and actual (in the case of subsequent notification) date, time, and duration of implementation of the Customer Demand Management; and (b) The magnitude of the proposed reduction by the use of Customer Demand Management. The Distribution Utility shall provide the System Operator with the amount of Demand reduction actually achieved by the use of the Customer Demand Management. 6.6.4.3 If the Demand Control involves the disconnection of an industrial circuit, Voluntary Load Curtailment (VLC) or any similar scheme shall be implemented wherein the Customers are divided into VLC Weekday groups (e.g., Monday Group, Tuesday Group, etc.). Customers participating in the VLC shall voluntarily reduce their respective Demands for a certain period of time depending on the extent of the generation deficiency. Industrial Customers or Commercial Customers who implemented a VLC shall provide the Distribution Utility with the amount of Demand reduction actually achieved through the VLC scheme. 98 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.6.5 Voltage Control The control of Voltage can be achieved by managing the Reactive Power supply in the Distribution System. This shall include the operation of the following Equipment: (a) Embedded Generating Units; (b) Synchronous condensers; (c) Static VAR compensators; (d) Shunt capacitors and reactors; and (e) On-Load tap changing Transformers. In order to perform the control of Voltage, the Distribution Utility will send the instructions it considers appropriate to the Large Conventional, Large VRE or Medium Embedded Generating Plant, provided such instructions imply providing Reactive Power within the limits indicated in Sections 4.5.5, 4.6.3 and 4.7.3, as appropriate. 6.7 EMERGENCY PROCEDURES 6.7.1 Preparation for Distribution Emergencies 6.7.1.1 The Distribution Utility shall issue a directive to any User for the purpose of mitigating the effects of the disruption of electricity supply attributable to any of the following: (a) Natural disaster; (b) Civil disturbance; or (c) Fortuitous Event. 6.7.1.2 The User shall provide the Distribution Utility, in writing, copy furnished the Supplier, the contact numbers of persons who can make binding decisions on the User System when there is a Significant Incident. 6.7.1.3 The Distribution Utility shall develop and maintain a Manual of Distribution Emergency Procedures, which shall include a list of all the parties to be notified in cases of emergencies, and their business and home contact numbers. 6.7.1.4 Emergency drills shall be conducted at least once a year to familiarize all personnel responsible for emergencies. The drills shall simulate realistic emergency situations. A drill evaluation shall be performed and deficiencies in procedures and responses shall be identified and corrected. 6.7.1.5 The User shall participate in all emergency drills organized by the Distribution Utility. 6.7.2 Significant Incident Procedures 6.7.2.1 Following the issuance of a Significant Incident Notice by the Distribution Utility or a User, any User may file a written request to the Distribution Utility for a joint investigation of the Significant Incident. If there have been several Significant Incidents, the joint investigation may include the other Significant Incidents. December 2017 99 Philippine Distribution Code 2017 Edition Distribution Operations 6.7.2.2 A joint investigation of the Significant Incident shall be conducted only when the Distribution Utility and the Users have reached an agreement to conduct the joint investigation. 6.7.2.3 The Distribution Utility shall submit a written report to the DMC and the ERC detailing all the information, findings, and recommendations regarding the Significant Incident. 6.7.2.4 The following minimum information shall be included in the written report following the joint investigation of the Significant Incident: (a) Time and date of the Significant Incident; (b) Location of the Significant Incident; (c) Equipment directly involved and not merely affected by the Event; (d) Description of the Significant Incident; and (e) Demand (in MW) and generation (in MW) interrupted and the duration of the Interruption. 6.7.3 Operation of Embedded Generating Unit in Island Grid 6.7.3.1 If a part of the Distribution System to which an Embedded Generating Unit is connected becomes isolated from the Distribution System, both the Distribution Utility and the Embedded Generation Company shall determine and agree if it is possible and desirable for the Embedded Generating Unit to continue operating. 6.7.3.2 If no facilities exist for the subsequent resynchronization with the rest of the Distribution System, the Distribution Utility shall issue an instruction to the Embedded Generation Company to disconnect its Generating Unit so that the Island Grid may be reconnected to the rest of the Distribution System. 6.7.4 Black Start and Resynchronization Procedures 6.7.4.1 If a Significant Incident resulted in a Total System Blackout or a Partial System Blackout and the isolated Distribution System has Embedded Generating Units with Black Start Capability, the Distribution Utility shall initiate a Black Start procedure in coordination with the System Operator. 6.7.4.2 The System Operator, pursuant to the procedures in the latest edition of the Philippine Grid Code, shall be responsible in the resynchronization of the Island Grids after the Black Start procedure or after a Significant Incident has resulted in Island Grid operation. 6.7.4.3 After a Total System Blackout or a Partial System Blackout and during the whole restoration process, Embedded Generation Companies of Large and Medium Embedded Generating Plants shall strictly follow the instructions issued by the System Operator through the Distribution Utility. They shall not reconnect to the network unless an instruction or an authorization has been provided by the System Operator or the Distribution Utility. 100 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.8 SAFETY COORDINATION 6.8.1 Safety Coordination Procedures 6.8.1.1 The Distribution Utility and the User shall adopt and use a set of Safety Rules and Local Safety Instructions for implementing Safety Precautions on MV and HV Equipment. The respective Safety Rules and Local Safety Instructions of the Distribution Utility and the User shall govern any work or testing on the Distribution System or the User System. 6.8.1.2 The Distribution Utility shall furnish the User a copy of its Safety Rules and Local Safety Instructions relating to the Safety Precautions on its MV and HV Equipment. 6.8.1.3 The User shall furnish the Distribution Utility a copy of its Safety Rules and Local Safety Instructions relating to the Safety Precautions on its MV and HV Equipment. 6.8.1.4 Any party who wants to amend any provision of or revise its Local Safety Instructions shall provide the other party with the amended or revised copy of the Local Safety Instructions. 6.8.1.5 Safety coordination procedures shall be established for the coordination, establishment, maintenance, and cancellation of Safety Precautions on MV and HV Equipment when work or testing is to be carried out in the Distribution System or the User System. 6.8.1.6 Work or testing on any Equipment at the Connection Point shall be carried out only in the presence of the representatives of the Distribution Utility and the User. 6.8.1.7 The User (or the Distribution Utility) shall seek authority from the Distribution Utility (or the User) if it wishes to access any Distribution Utility’s (or User’s) Equipment. 6.8.1.8 If work or testing is to be carried out in the Distribution System and a Safety Precaution is required on the MV and HV Equipment of several Users, the Distribution Utility shall ensure that the Safety Precautions in the Distribution System and on the System of all Users involved are coordinated and implemented. 6.8.1.9 If work or testing is to be carried out in the Distribution System and a User becomes aware that Safety Precautions are also required in the System of other Users, the Distribution Utility shall be promptly informed of the required Safety Precautions in the System of the other Users. The Distribution Utility shall ensure that Safety Precautions are coordinated and implemented in the Distribution System and the Systems of the affected Users. 6.8.2 Safety Coordinator 6.8.2.1 The Distribution Utility and the User shall assign a Safety Coordinator who shall be responsible for the coordination of Safety Precautions on the MV and HV Equipment at their respective sides of the Connection Point. Any party who wants to change its Safety Coordinator shall notify the other party of the change. December 2017 101 Philippine Distribution Code 2017 Edition Distribution Operations 6.8.2.2 For purposes of safety coordination, the Safety Coordinator requesting that a Safety Precaution be applied on the System of the other party shall be referred to as the Requesting Safety Coordinator while the Safety Coordinator that will implement the requested Safety Precaution shall be referred to as the Implementing Safety Coordinator. 6.8.2.3 If work or testing is to be carried out in the Distribution System (or the User System) that requires Safety Precautions on the MV and HV Equipment of the User System (or the Distribution System), the Requesting Safety Coordinator shall contact the Implementing Safety Coordinator to coordinate the necessary Safety Precautions. 6.8.2.4 If a Safety Precaution is required for the MV and HV Equipment of other Users who were not mentioned in the request, the Implementing Safety Coordinator shall promptly inform the Requesting Safety Coordinator. 6.8.2.5 If a Safety Precaution becomes ineffective, the concerned Safety Coordinator shall inform the other Safety Coordinators about it without delay, and stating the reasons why the Safety Precaution has lost its integrity. 6.8.3 Safety Logs and Record of Inter-System Safety Precautions 6.8.3.1 The Distribution Utility and the User shall maintain Safety Logs to record, in chronological order, all messages relating to Safety Coordination. The Safety Logs shall be retained for at least 1 year. 6.8.3.2 The Distribution Utility shall establish a record of inter-system Safety Precautions to be used by the Requesting Safety Coordinator and the Implementing Safety Coordinator in coordinating the Safety Precautions on MV and HV Equipment. The record of intersystem Safety Precautions shall contain the following information: (a) Site and Equipment Identification of MV or HV Equipment where the Safety Precaution is to be established or has been established; (b) Location and the means of implementation of the Safety Precaution; (c) Confirmation of the Safety Coordinator that the Safety Precaution has been established; and (d) Confirmation of the Safety Coordinator that the Safety Precaution is no longer needed and has been cancelled. 6.8.4 Location of Safety Precautions 6.8.4.1 When work or testing is to be carried out in the Distribution System (or the User System) and Safety Precautions are required in the User System (or the Distribution System), the Requesting Safety Coordinator shall contact the concerned Implementing Safety Coordinator to agree on the locations where the Safety Precautions will be implemented or applied. The Requesting Safety Coordinator shall specify the proposed locations at which Isolation and/or Grounding are to be established. 6.8.4.2 In the case of Isolation, the Implementing Safety Coordinator shall promptly notify the Requesting Safety Coordinator of the following: 102 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition (a) The Identification of each Point of Isolation using the Site and Equipment Identification specified in Article 6.12; and (b) The means of implementing Isolation as specified in Section 6.8.5. 6.8.4.3 In the case of Grounding, the Implementing Safety Coordinator shall promptly notify the Requesting Safety Coordinator of the following: (a) The Identification of each Point of Grounding using the Site and Equipment Identification specified in Article 6.12; and (b) The means of implementing Grounding as specified in Section 6.8.5. 6.8.4.4 If the Requesting Safety Coordinator and the Implementing Safety Coordinator do not agree on the location, Grounding shall be established at the available point on the infeed closest to the MV and HV Equipment. 6.8.5 Implementation of Safety Precautions 6.8.5.1 Once the locations of Isolation and Grounding have been agreed upon, the Implementing Safety Coordinator shall ensure that the Isolation is implemented. 6.8.5.2 The Isolation shall be implemented by any of the following: (a) A disconnect switch, or other isolating means, that is secured in an open position by a lock and affixing a Safety Tag to it or by such other method in accordance with the Local Safety Instructions of the Distribution Utility or of the User, as the case may be; or (b) An adequate physical separation (e.g., Grounding Cluster) in accordance with the Local Safety Instructions of the Distribution Utility or of the User. In addition, a Safety Tag shall be placed at the switching points. 6.8.5.3 The Implementing Safety Coordinator, after the required Isolation in all locations had been established in his System, shall notify the Requesting Safety Coordinator that the required Isolation has been implemented. 6.8.5.4 After the confirmation of Isolation, the Requesting Safety Coordinator shall inform the former of the establishment of relevant Isolation, if any, on his System and request, if required, the implementation of Grounding. 6.8.5.5 The Implementing Safety Coordinator shall ensure the implementation of Grounding and notify the Requesting Safety Coordinator that Grounding has been established in his System. 6.8.5.6 Grounding shall be implemented by any of the following: (a) A Grounding switch secured in a closed position by a lock and affixing a Safety Tag to it or by such other method in accordance with the Local Safety Instructions of the Distribution Utility or of the User, as the case may be; or (b) An adequate physical connection (e.g., Grounding Cluster) which shall be in accordance with the methods set out in the Local Safety Instructions of the Distribution Utility or those of the User. In addition, a Safety Tag shall be placed at the point of connection and all related switching points. December 2017 103 Philippine Distribution Code 2017 Edition Distribution Operations 6.8.5.7 If the disconnect switch or the Grounding switch is locked with its own locking mechanism or with a padlock, the key shall be secured in a key cabinet. 6.8.6 Authorization of Testing If the Requesting Safety Coordinator wishes to authorize a test on MV or HV Equipment, he shall only do so after the following procedure has been implemented: (a) Confirmation is obtained from the Implementing Safety Coordinator that no person is working on or testing, or has been authorized to work on or test, any part of his System within the Points of Isolation identified; (b) All Safety Precautions other than the current Safety Precautions have been cancelled; and (c) The Implementing Safety Coordinator agrees with him on the conduct of testing in that part of the System. 6.8.7 Cancellation of Safety Precautions 6.8.7.1 When the Requesting Safety Coordinator decides that Safety Precautions are no longer required, he shall contact the Implementing Safety Coordinator and inform him that the Safety Precautions are no longer required. 6.8.7.2 Both coordinators shall then cancel the Safety Precautions. 6.9 DISTRIBUTION TESTING AND MONITORING 6.9.1 Testing Requirements 6.9.1.1 The Distribution Utility shall, from time to time, determine the need to test and/or monitor the Power Quality at various points on its Distribution System. 6.9.1.2 The requirement for specific testing and/or monitoring by a Distribution Utility shall be initiated by the receipt of a complaint relating to Power Quality in the Distribution System. 6.9.1.3 In certain situations, the Distribution Utility may require the testing and/or monitoring to take place at the Connection Point of a User to be witnessed by a User representative. 6.9.1.4 If testing and/or monitoring is required at the Connection Point, the Distribution Utilities shall advise the User involved and shall make available the results of such tests to the User. 6.9.1.5 Upon the request of the User, a retest shall be carried out. The cost of the retest shall be charged to the User. 6.9.1.6 If the results of the test show that the User is operating outside the technical parameters specified in Sections 4.2.5, 4.2.6, and 4.2.7, the User shall be informed accordingly. The User shall rectify the situation within such period of time as agreed upon with the Distribution Utility. 104 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.9.1.7 If the User failed to rectify the situation, the Distribution Utility may disconnect the User from the Distribution System, in accordance with the Connection Agreement or Amended Connection Agreement. 6.9.2 Monitoring of User Effect on the Distribution System 6.9.2.1 The Distribution Utility shall, from time to time, monitor the effect of the User System in the Distribution System. 6.9.2.2 The monitoring shall normally be related to the amount of Active Power and Reactive Power transferred across the Connection Point. 6.9.2.3 If the User is exporting (or importing) from the Distribution System a Demand in excess of the value specified in the Connection Agreement or Amended Connection Agreement, the Distribution Utility shall inform the User. Upon the request of the User, the Distribution Utility shall demonstrate the results of such monitoring. 6.9.2.4 The User may request technical information from the Distribution Utility on the method of monitoring adopted, and if necessary, request to use another method that is acceptable to the Distribution Utility. 6.9.2.5 If the User is operating outside the limits specified in Sections 4.2.5, 4.2.6, and 4.2.7, the User shall immediately restrict the Demand transfer to within the value specified in the Connection Agreement or Amended Connection Agreement. The restriction shall be in effect until a new Amended Connection Agreement is signed and the necessary changes in the Connection Point are undertaken. 6.9.2.6 If the User’s Demand is in excess of the rated capacity of the Connection Point, the User shall limit the Demand transfer to the value specified in the Connection Agreement or Amended Connection Agreement. 6.10 SYSTEM TEST 6.10.1 System Test Requirements 6.10.1.1 System Test, which involves the simulation of conditions or the controlled application of unusual or extreme conditions that may have an impact on the Distribution System or the User System, shall be carried out in a manner that shall not endanger any personnel or the general public. 6.10.1.2 The possibility of damage to Equipment, the Distribution System, and the System of the Users shall be minimized when undertaking a System Test on the Distribution System or the User System. 6.10.1.3 Where the System Test may have an impact on the Grid, the procedure specified in the Philippine Grid Code shall be used in carrying out the proposed System Test. 6.10.2 System Test Request 6.10.2.1 If a User wishes to undertake a System Test on its System, it shall submit to the Distribution Utility a System Test Request that contains the following: (a) The purpose and nature of the proposed System Test; December 2017 105 Philippine Distribution Code 2017 Edition Distribution Operations (b) The extent and condition of the Equipment involved; and (c) A proposed System Test Procedure specifying the switching sequence and the timing of the switching sequence. 6.10.2.2 The System Test Proponent shall provide sufficient time for the Distribution Utility to plan the proposed System Test. The Distribution Utility shall determine the time required for each type of System Test. 6.10.2.3 The Distribution Utility may require additional information before approving the proposed System Test if the information contained in the System Test Request is insufficient, or the proposed System Test Procedure cannot ensure the safety of personnel and Reliability of the Distribution System. 6.10.2.4 The Distribution Utility shall determine and notify other Users other than the System Test Proponent that may be affected by the proposed System Test. 6.10.2.5 The Distribution Utility may also initiate a System Test if it determined that the System Test is necessary to ensure the safety and Reliability of the Distribution System. 6.10.3 System Test Group 6.10.3.1 If the Distribution Utility is the System Test Proponent, it shall notify all affected Users of the proposed System Test. If the Distribution Utility is not the System Test Proponent, it shall notify, within 1 month after the acceptance of a System Test Request, the System Test Proponent and the affected Users of the proposed System Test. The notice shall contain the following: (a) The purpose and nature of the proposed System Test, the extent and condition of the Equipment involved, the identity of the System Test Proponent, and the affected Users; (b) An invitation to nominate representatives for the System Test Group to be established to coordinate the proposed System Test; and (c) If the System Test involves work or testing on MV and HV Equipment, the Safety Coordinators and the safety procedure specified in Article 6.8. 6.10.3.2 The Distribution Utility, the System Test Proponent (if it is not the Distribution Utility) and the affected Users shall nominate their representatives to the System Test Group within 1 month after receipt of the notice from the Distribution Utility. The Distribution Utility may decide to proceed with the proposed System Test even if the affected Users fail to reply within that period. 6.10.3.3 The Distribution Utility shall establish a System Test Group and appoint a System Test Coordinator, who shall act as chairman of the System Test Group. The System Test Coordinator may come from the Distribution Utility or the System Test Proponent. 6.10.3.4 The members of the System Test Group shall meet within 1 month after the Test Group is established. The System Test Coordinator shall convene the System Test Group as often as necessary. 106 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition 6.10.3.5 The agenda for the meeting of the System Test Group shall include the following: (a) The details of the purpose and nature of the proposed System Test and other matters included in the System Test Request; (b) Evaluation of the System Test Procedure as submitted by the System Test Proponent and making the necessary modifications to come up with the final System Test Procedure; (c) The possibility of scheduling simultaneously the proposed System Test with any other test and with Equipment Maintenance which may arise pursuant to the Maintenance Program requirements of the Distribution System or the System of the Users; and (d) The economic, operational, and risk implications of the proposed System Test on the Distribution System, the System of the other Users, and the Scheduling and Dispatch of the Embedded Generating Plants. 6.10.3.6 The Distribution Utility, the System Test Proponent (if it is not the Distribution Utility) and the affected Users (including those which are not represented in the System Test Group) shall provide the System Test Group, upon request, with such details as the System Test Group reasonably requires to carry out the proposed System Test. 6.10.4 System Test Program 6.10.4.1 Within 2 months after the first meeting and at least 1 month prior to the date of the proposed System Test, the System Test Group shall submit to the Distribution Utility, the System Test Proponent (if it is not the Distribution Utility), and the affected Users a proposed System Test Program which shall contain the following: (a) Plan for carrying out the System Test; (b) System Test Procedure to be followed during the test including the manner in which the System Test is to be monitored; (c) List of responsible persons, including Safety Coordinators when necessary, who will be involved in carrying out the System Test; (d) An allocation of the testing cost among the affected parties; and (e) Such other matters as the System Test Group may deem appropriate and necessary and are approved by the management of the affected parties. 6.10.4.2 If the proposed System Test Program is acceptable to the Distribution Utility, the System Test Proponent, and the affected Users, the final System Test Program shall be constituted and the System Test shall proceed accordingly. Otherwise, the System Test Group shall revise the System Test Program. 6.10.4.3 If the System Test Group is unable to develop a System Test Program or reach a decision in implementing the System Test Program, the Distribution Utility shall determine whether it is necessary to proceed with the System Test to ensure the safety and Reliability of the Distribution System. December 2017 107 Philippine Distribution Code 2017 Edition Distribution Operations 6.10.4.4 The System Test Coordinator shall be notified in writing, as soon as possible, of any proposed revision or amendment to the System Test Program prior to the day of the proposed System Test. If the System Test Coordinator decides that the proposed revision or amendment is meritorious, he shall notify the Distribution Utility, the System Test Proponent and the affected Users to act accordingly for the inclusion thereof. The System Test Program shall then be carried out with the revisions or amendments if the System Test Coordinator received no objections. 6.10.4.5 If System conditions are abnormal during the scheduled day for the System Test, the System Test Coordinator may recommend a postponement of the System Test. 6.10.5 System Test Report 6.10.5.1 Within 2 months or a shorter period as the System Test Group may agree after the conclusion of the System Test, the System Test Proponent shall prepare and submit a System Test Report to the Distribution Utility, the affected Users, and the members of the System Test Group. 6.10.5.2 After the submission of System Test Report, the System Test Group shall be automatically dissolved. 6.10.5.3 The Distribution Utility shall submit the System Test Report to the DMC for its review and recommendations. 6.11 EMBEDDED GENERATING UNIT CAPABILITY TESTS 6.11.1 Test Requirements For Large and Medium Embedded Generating Units 6.11.1.1 Tests shall be conducted, in accordance with the agreed procedures and standards, to confirm the compliance of Large and Medium Embedded Generating Units for the following: (a) Capability of Generating Units to operate within their registered Generation parameters; (b) Capability of the Generating Units to meet the applicable requirements of the Philippine Grid Code and the Philippine Distribution Code; (c) Capability to deliver the Ancillary Services that the Embedded Generation Company had agreed to provide; and (d) Availability of Generating Units in accordance with their capability declaration. 6.11.1.2 All tests shall be recorded and witnessed by the authorized representatives of the Distribution Utility, Embedded Generation Company, and/or User. 6.11.1.3 The Embedded Generation Company shall demonstrate to the Distribution Utility the reliability and accuracy of the test instruments and Equipment to be used in the test. 6.11.1.4 The Distribution Utility may at any time, issue instructions requiring tests to be carried out on any Large and Medium Embedded Generating Unit. All tests shall be of sufficient duration and shall be conducted no 108 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition more than twice a year except when there are reasonable grounds to justify the necessity for further tests. 6.11.1.5 If an Embedded Generating Unit fails the test, the Embedded Generation Company shall correct the deficiency within an agreed period to attain the relevant registered parameters for that Embedded Generating Unit. 6.11.1.6 Once the Embedded Generation Company achieves the registered parameters of its Embedded Generating Unit that previously failed the test, it shall immediately notify the Distribution Utility. The Distribution Utility shall then require the Embedded Generation Company to conduct a retest in order to demonstrate that the appropriate parameter has already been restored to its registered value. 6.11.1.7 If a dispute arises relating to the failure of an Embedded Generating Unit to pass a given test, the Distribution Utility, the Embedded Generation Company, and/or User shall seek to resolve the dispute among themselves. 6.11.1.8 If the dispute cannot be resolved, one of the parties may submit the issue to the ERC, through the DMC. 6.11.2 Tests to be Performed for Large and Medium Embedded Generating Units 6.11.2.1 The Reactive Power Test shall demonstrate that the Large or Medium Embedded Generating Unit meets the registered Reactive Power Capability requirements specified in Sections 4.5.5, 4.6.3 or 4.7.3 as applicable. The Embedded Generating Unit shall pass the test if the measured values are within ±5% of the Capability as registered with the Transmission Network Provider through the Distribution Utility. 6.11.2.2 The Frequency Withstand Test shall demonstrate that the Large or Medium Embedded Generating Unit has the capability to remain Synchronized to the network for the time prescribed in Sections 4.5.2, 4.6.2 or 4.7.2, as applicable. The Generating Unit shall pass the test if it does not disconnect when System Frequency is within the permissible values. 6.11.2.3 The Primary Response Test shall demonstrate that the Large or Medium Embedded Generating Unit has the capability to provide Primary Response, as specified in Section 4.5.7, 4.6.5 or 4.7.4, as applicable. The Generating Unit shall pass the test if the measured response in MW/Hz is within ±5% of the required level of response within 5 seconds. 6.11.2.4 The Reactive Power Control Test shall demonstrate that the Large or Medium Embedded Generating Unit has the capability to control the Reactive Power at the Connection Point, as specified in Section 4.5.6, 4.6.4 or 4.7.3, as applicable. The Embedded Generating Plant shall pass the test if: (a) In Voltage control mode, the Large Embedded Generating Plant is capable to control the Voltage at the Connection Point within a margin not greater than 0.01 p.u., provided the Reactive Power injected or absorbed is within the limits specified in Section 4.5.5 or 4.6.3, as December 2017 109 Philippine Distribution Code 2017 Edition Distribution Operations corresponds, with a steady state reactive tolerance no greater than 5% of the maximum Reactive Power. (b) Following a step change in Voltage, the Large Embedded Generating Unit shall be capable of achieving 90% of the change in Reactive Power output within a time less than 5 seconds, reaching its final value within a time no greater than 30 seconds. (c) In Power Factor control mode, the Large or Medium Embedded Generating Plant is capable of controlling the Power Factor at the Connection Point within the required Reactive Power range, with a target Power Factor in steps no greater than 0.01. 6.11.2.5 The Fast Start Capability Test shall demonstrate that the Embedded Generating Unit has the capability to automatically Start-Up, synchronize with the Grid through the Distribution System and be loaded up to its offered capability, as specified in Section 4.4.4. The Embedded Generating Unit shall pass the test if it meets the Fast Start capability requirements. 6.11.2.6 The Black Start Test shall demonstrate that the Embedded Generating Unit with Black Start capability can implement a Black Start procedure, as specified in Section 4.4.3. To pass the test, the Embedded Generating Unit shall start on its own, synchronize with the Grid through the Distribution System and carry load without the need for external power supply. 6.11.2.7 The Declared Data Capability Test, to be performed to Large Conventional or Large VRE, Medium Embedded Generation Company shall demonstrate that the Embedded Generating Unit can be scheduled and dispatched in accordance with the Declared Data. To pass the test, the Embedded Generating Unit shall satisfy the ability to achieve the Declared Data. 6.11.2.8 The Dispatch Accuracy Test, to be performed to Large or Medium Embedded Generation Company shall demonstrate that the Embedded Generating Unit meets the relevant Dispatch Scheduling and Dispatch Parameters. The Embedded Generating Unit shall pass the test if: (a) In the case of synchronization, the process is achieved within ±5 minutes of the registered synchronization time; (b) In the case of synchronizing generation (if registered as a Dispatch Scheduling and Dispatch Parameters), the synchronizing generation achieved is within an error level equivalent to 2.5% of Net Declared Capacity; (c) In the case of meeting ramp rates, the actual ramp rate is within ±10% of the registered ramp rate; (d) In the case of meeting Load reduction rates, the actual Load reduction rate is within ±10% of the registered load reduction rate; and (e) In the case of all other Dispatch Scheduling and Dispatch Parameters, values are within ±1.5% of the declared values. 6.11.2.9 The SCADA and communications tests shall demonstrate that the Large or Medium Embedded Generating Unit is capable to: 110 December 2017 Distribution Operations Philippine Distribution Code 2017 Edition (a) Receive active power or Voltage set-points and/or disconnection signals issued from the Distribution Utility or from the System Operator SCADA through the Distribution Utility, provided that such possibilities has been agreed in the Connection Agreement and/or Amended Connection Agreement; and (b) Send to the Distribution Utility the signals indicated in the Connection Agreement or Amended Connection Agreement. 6.11.2.10 The Protections Tests shall demonstrate that all the protections agreed with the Distribution Utility perform with the required speed and selectivity settings. It shall also demonstrate that the Embedded Generating Unit disconnects from the Distribution System in case of Loss of Mains. 6.11.2.11 The Ancillary Services acceptability test shall determine the committed services in terms of parameter quantity or volume, timeliness, and other operational requirements. Generation Companies providing Ancillary Services shall conduct the test or define the committed service. However, monitoring by the System Operator or the Distribution Utility of the Ancillary Services performance in response to System-derived inputs shall also be carried out. 6.11.2.12 Following tests can be performed for Large or Medium Embedded Generating Units in cases that, based on an analysis of one or more network incidents or claims, the System Operator, the Distribution Utility, the DMC or the ERC has grounds to consider the performance of the Embedded Generating Plant is not complying with the prescriptions stated in the Philippine Distribution Code: (a) The Power Q

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