Biennial ICPM Manual

8/10/2019 Biennial ICPM Manual

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REPUBLIC OF THE PHILIPPINES

NATIONAL ELECTRIFICATIONADMINISTRATIONQUEZON CITY

5 7 N I A R O A D G O V E R N M E N T C E N T E R , D I L I M A N , Q U E Z O N C I T Y


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BIENNIAL INTEGRATED COMPUTERIZED PLANNING MODEL (ICPM)NATIONAL

ELECTRIFICATION

ADMINISTRATION

ENHANCEMENT OF INTEGRATED COMPUTERIZED

PLANNING MODEL (ICPM)

NEA Office Order No. 2009-131, Series of 2009

Creation of Technical Working Group for Enhancement of Integrated

Computerized Planning Model (ICPM) in accordance with ECs

Distribution Utility Planning Manual (EC-DUP).

NEA Office Order No. 2009-150, Series of 2009

Creation of NEA Team on the Training and Capability Building forCAPEX Plan

RATIONALE:

NEA Administrator Memorandum No. 2009-014 Re: CAPEX Plan

Preparation:

ECs to await the culmination of the Trainors Training Seminar Workshop

prior to the engagement with Capex Application Consultants to ensure

alignment with ERC format and attain the following objectives.

Harmonizing the identified infrastructures projects of each

respective EC as stated in its ICPM, DDP, Capex Applications, Rate

Filing and other related documents.

Facilitating a common, well understood, simple framework,

template and manual covering the entire CAPEX Application cycle.

Capacitating Core NEA/Regional Association /EC personnel on

CAPEX Application procedures and preparations with ERC.

Memorandum of Agreement dated August 05, 2009 on the crafted

and formulated Electric Cooperative Distribution Utility Planning

Manual a necessity to adopt a comprehensive and integrated

development plan for the preparation of the CAPEX Projects,

programs, structural and/or institutional planning and development

of the ECs consistent with PDC, Safety Standards set by PEC,

Resolution No. 18s ,2008 and Resolution No. 26s, 2009 ,Rules and

Regulations issued by ERC, the DDP and the ICPM and other

applicable and pertinent laws.


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INTEGRATED COMPUTERIZED PLANNING MODEL (ICPM)USERs MANNUAL

It is advisable to use a Computer Workstation with a high Technical

Specifications and should be run with Microsoft Office Excel 2007, due to

the multiple Worksheet Links, Graph Displays and various Formula

Calculations involved in processing the e-ICPM.

GENERAL GUIDELINES IN USING THE ICPM

1. Installation of ICPM to your computer:

a. Insert the generic blank ICPM model in your CD drive/ external USB

b. Copy all contents on the Desktop Display of your computer

2. To Save all finished modules in Technical, Financial and Institutional

aspects, as shown below are the options per users:

a. For Single-Computer users, save it normally

after every process

b.

For Multi-Computer users, copy the folder to

merge all files and save it through Copy and

Replace option

c. You can rename any Folders but not the File

within

3. To Print: You can print worksheets using the Print

menu of Excel

Note:Do not change the File extension (.xlsm)


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GETTING STARTED:

ADJUSTMENT OF SECURITY SETTINGS

MS Excel 2007 Version

a. Go to Office Menu

b. Find Excel Option

c. Trust Center

d. Click Trust Center Setting

e. Macro Setting

Enable all MacrosCheck trust access to VBA project

object model

f. Then click OK

DEACTIVATION OF AUTOSAVE OPTIONS

MS Office 2007 Version

a. Go to Office Menu

b. Find Excel Optionc. Click Saveo Uncheck "Save AutoRecover

Information for every"

b

a

d

e

f

b

a

b

c

c


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FORECASTING

The ability of the electric cooperative to accurately forecast future energy and

demand requirement of the distribution system is a critical component for effective

and correct identification of CAPEX projects. Inaccurate forecast may result to

wrong prescription of projects by the system managers or planners, either byoverbuilding or under-building capacity. In any case, this would result in significantcost to the consumers.

FORECASTING APPROACHES AND METHODOLOGY

The most appropriate forecasting methodology for distribution utilities is SmallArea forecasting to capture both magnitude and spatial characteristics of the

load within the franchise or coverage area of the utility company. However, the

current state of database and analytical models of the Electric Cooperatives are

not sufficient yet to apply this approach or methodology. There are two

forecasting methodology that can be used by the ECs. These are theEconometric Analysis and Trend Analysis

There are also two (2) approaches in forecasting the Peak Demand. The first

approach is to forecast the peak demand directly. The second approach is toforecast energy first then compute the peak demand from an assumed load

factor. The Distribution Planner must assess which approach is best for the data

available

TESTING AND IMPROVING THE FORECASTING MODELS

The forecasting models formulated must be tested for validity. The R2 andAdjusted R2 statistics are good measure of fit of the model to the historical data.

These statistics must be used to assess whether the addition of independentvariable are valid or not. For econometric models, the Adjusted R2 statistic should

be at least 80% while for trend models, it should be at least 99% for the model to

be valid. Predictors or independent variables must also be tested for their validity

using at least the p-value and t-statistic. For the variable to be valid, the p-value

should be lower than 0.1 while the t-statistic should be greater than 2 or less than

-2. For all the valid forecasting models formulated, the Mean Absolute

Percentage Error (MAPE) must be computed. The MAPE of the final forecasting

model should not exceed 5%.

In case, the forecasting models formulated failed either or both in terms ofvalidity and accuracy, the Distribution Planner must improve the model by using

additional data or through some variants of the model.

DEMAND AND CUSTOMER FORECASTS

The EC must forecast the following:

o Annual peak demand and energy for each substation for 10 years;

o Annual Sales or Customer Consumption per customer class for 10 years;

o

Annual Number of customers per customer class for 10 years;


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I. FORECASTED DATA FILE

1. Input you Username and

Password "binnialicpm" then click

Submit

2. The ability of Electric

Cooperatives to accurately

forecast future energy

and demand

requirement of the

distribution system is a

critical component for

effective and correctidentification of CAPEX

projects. Inaccurate

forecast may result to

wrong prescription of

projects by the system

planners either by overbuilding or under-building capacity. In any

case, this would result in significant cost to the customers.

3. Fill-up the General Informationthen Save

4. Customer Classification Entry, Under Residential, Low Voltage and

Higher Voltage Input the customer classification based on ERC

approved RSEC-WR for On-Grid ECs. For Off-Grid ECs, click the

Customer Entry under Low Voltage then type the customers,

Commercial, Industrial, Irrigation, PB, St. Lights and Others

Press

OK


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5. On the Substation Options select the Substation No. 1/Power Plant

No. 1 then click Start

6. Input the Seven Years Historical Energy Data in MWH, Peak Demand

in MW to include customer under Higher Voltage (for On-Grid ECs)

and Number of Customer under the Substation/Power Plant you

have forecast then click Save.

Note:all white cell are input area, the highlighted cell is

calculated automatically

7. Click Forecasted Data input the forecasted energy in MWH, Peak

Demand in MW per Substation/Power Plant and Number of

Customer based on forecasting model.

8. Input Coop Use (MWH) and Target for Technical and Non-Technical

Loss Reduction based on your Simulation (input data on white cells)

then click Saveand press Potential Large Loadbutton.

Input Substation

Name and Location


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11.Click Total Forecastto view and review the inputted data.

12.Click Narrative Report to attach Load Forecasting Summary based

on your selected forecasting models used.

13.Then click Save on this button, the EC must execute to save and

wait for the process to complete then click Close.


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II. LONG-TERM DEVELOPMENT PLAN FILE


Password "biennialicpm" then

Click Submit

2. This is a pre-requisite of Load Flow

Simulation using engineering

analysis softwares or manual

technical studies

conducted by the EC.

Prior to the use of this

model, we are

encouraging the EC to

undertake Electric

Distribution System

Analyses including

PDC/PGC and PEC

trainings. We presume that all projects listed have corresponding

justifications, i.e., Capex Network Projects or support engineering

studies including least cost bases.

3. Fill-up the General Information then Save

4. Before you proceed , click Link Filesfor updating, to capture the

necessary data

5. Highlight the Filename Forecast Data workbook, click Update Values

button and the click close

Press

OK


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6. Click Distribution Development Projects, this button will bring to the

list of infrastructure/projects:

7. Under the Distribution Plant or Network Assetswe have:

Electrification, Reliability, Power Quality, Systems Loss, Capacity and

other infrastructure Projects.


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8. For sitio electrification under the NEA Sitio Electrification Program

(SEP) Input NEA under Fund Source/s

o Primary Distribution Subsidy Projects (Sitio and Brgy. Line Enhancement)o

Primary Distribution Non-Subsidy Projectso Submarine and Underground Cable Projects

o Land and Land Rights

o User Development Projects (Large Load) Dedicated Circuit

o Renewable Energy Projects

9. Reliability Project:

o

Looping of Subtransmission Systemo Looping of Distribution System

o Installation of sectionalizing devices to improve SAIFI and MAIFI

o Installation of switching devices to improve SAIDI

o Conducting Transformer Load Management (TLM)

o Conducting preventive Subtransmission/Distribution Line

maintenance and ROW clearing


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10.Power Quality Project:

o Capacitor replacement and installation

o

Installation of AVR, OLTC etc.o Conductor Uprating

o Reconfiguration of Primary Distribution Line

o Installation of New Power Transformer

o Setting of Tap Change including DX Transformer

11.System Loss Project:

o Power Factor Improvement

o Conductor Uprating

o System Uprating / Feeder Configuration

o Rationalization of Distribution Capacity (TLM)

o Development of Subtransmission and Substation


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12.Logistical I.T. Equipment

o Information Technology Equipment Listing and Cost

Estimate/Fund Sources

13.Substransmission Development Project:

o Acquisition of Subtransmission Line

o Refurbishment or Rehabilitation

o Reinforcement or Construction


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14.Substation Project

o New Power Transformer and Substation Equipment

o Rehab and Uprating of Power Transformer and Substation

Equipment

15.Ad-Ons Customer Requirements

o Distribution Transformers, Meter and Service Drops Projects

o Secondary and Primary Line Expansion


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18.Click Compliance Planthere are 25Grid Codes and 50Distribution

Codes that will update the EC on their status of compliance. Some

PGC requires the EC to infuse Capital Expenditures.

19.

Click Optimal CAPEX Planto review the CAPEX Projects based on

EC-Distribution Utility Planning Manual as required by ERC.

20.Click Long Term Development Planthis button is linked to your

CAPEX Projects, including Physical Targets and Fund

21.Click Biennial Workplanthis button is your final output subject for the

approval of EC and NEA.

o The EC Project costs (LTDP-Summary) are already linked to the

Work Plan (WP) but the EC should input Project Descriptions,

Quarterly Targets, Project Impacts and Funding Source.

o Under the Project Impactspecify the expected end result of the

project/s

o The EC can insert rows as required. Then click Back

22.Click Contingency Plan and EC Buffer Stock in case of Emergency,

allocation for Material requirement is necessary to include in the

CAPEX

23.Click WESM Requirementsas the need arises

24.This is a Free Working Sheet(Technical and Economic Analysis)

25.Click Executive SummaryThis is the EC Business Plan/ Feasibility Study

Outline

26.Click Saveon this button, the EC must execute to save and wait for

the process to complete then Exit


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III. DOE - DISTRIBUTION DEVELOPMENT PLAN

CHAPTER I

BACKGROUND

1. Legal Basis

Rule 3 of the Implementing Rules and Regulations (IRR) of Republic Act

No.9136 (EPIRA) states that the Department of Energy (DOE) is mandated to

prepare and update annually the Power Development Program (PDP) and

Philippine Energy Plan (PEP). The PDP shall then consider and integrate the

Distribution Development Plan (DDP) of the Distribution Utilities (DUs).

Rule 7, Section 4 of the EPIRA-IRR indicates that the DUs shall prepare andsubmit to the DOE an annual five-year DDP not later than 15 thof March each

year. In the case of Electric Cooperatives (ECs), such plans shall be

submitted through National Electrification Administration (NEA) for review and

consolidation. Thus, NEA shall submit to DOE the consolidated ECs DDP not

later than 15thof March each year.

Department Circular No. 2004-02-002 prescribed the guidelines for the

formulation of a five-year DDP pursuant to Sec. 2 of Department Circular No.

DC2003-12-011. DC No. 2004-02-002 also prescribed two forms: (1)DOE-EPIMB

Form-03-001 (DDP Form); and (2) DOE-EPIMB Form 03-002 (BEP Form)

Since the PEP covers the ten-year planning horizon, the DUs are then required

to extend the five-year energy and demand forecast to a ten-year projection

to be consistent with the PEP.

In addition, Section 11 of Republic Act No. 9513 (Renewable Energy Act) and

Section 8 of its Implementing Rules and Regulations states that all DUs shall

include the required connection facilities for RE-based power facilities in the

DDP.


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2. Power Development Plan Structure

The structure of the PDP/PEP is shown below.

NECDDP: National Electric Cooperatives Distribution Development PlanMEDP : Missionary Electrification Development Plan

The DDP will also serve as reference in the determination of infrastructure

requirements to ensure quality, reliability, and security of supply at the

distribution level. This includes expansion and/or rehabilitation of the facilities.

The DDP is also a source of information for investment promotion and project

prioritization.

PEP

Energy ResourceDevelopment Plan

(DOE)

PhilippineDevelopment Plan

(DOE)

Energy Utility Plan

(DOE)

Transmission DevelopmentPlan

(TransCo/Concessionaire)

Distribution Development

Plan (DOE)

NECDDP(NEA) PIOUs DDP

(PIOUs)

MEDP

(DOE)

ECs DDP

(ECs)

WAIVED

AREAS


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CHAPTER II

OBJECTIVES

The DOEs Electric Power Industry Management Bureau (EPIMB), as part of its

mandate shall review the list of distribution development projects with the

view to encourage private sector participation under a competitive

environment. EPIMB shall also provide indicative timetables to ensure

sufficient lead times in the construction of power facilities.

The DOE's review of the DDPs shall take into account consistency with the

general and specific policies for the energy sector, the assumptions used in

formulation of such plans, and the consistency of such plans with national

and regional resource assessments, development programs, and project

timetables of various energy upstream activities.

The EPIMB shall also use the data described in the DDP for the following

purposes;

(1) validate electricity demand forecasts at the macro level in the next ten

(10) years; and

(2) simulate power supply plan based on the demand forecasts and come

up with indicative plant line-up

After evaluating the results of the simulations, the DOE, if necessary, requests

further clarification and/or amendments from concerned DUs. The EPIMB shall

recommend the DOEs approval and adoption of the DDPs and their

integration with the PDP/PEP no later than June 30 of each year.

The integrated PDP/PEP shall be submitted to the Congress on or before

September 15thevery year.


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Industry: establishments engaged in the extraction and/or processing

of materials, assembly, and other productive activities.

Other end usersmay include one of the following categories:

public buildings

street lighting

agricultural (includes aquaculture)

irrigation

municipal water pumping

transportation and communications

contractual export

others

ELECTRICITY CONSUMPTION: refers to the total amount of energy consumedduring the year. This will give an overview of the total power consumption in

the franchise area.

ELECTRIFICATION LEVEL: refers to the ratio of the total number of actual and

projected household connections over the number of potential household

connections.

EMBEDDED GENERATING PLANT: refers to a generating plant that is connected

to a distribution system or the system of any User (a person or entity that uses

the Distribution System and related Distribution facilities) and has no

connection to the Grid.

FRANCHISE: refers to the franchise, authority, or license under a Certificate of

Public Convenience and Necessity (CPCN) awarded by the Energy

Regulatory Commission (ERC) for private utilities, the NEA for ECs, or by Act of

the Congress of the Philippines.

FRANCHISE AREA: refers to a geographical area specifically defined and

described in its franchise.

GRID: refers to the high voltage backbone system of interconnectedtransmission line, substations, and related facilities, located in each of Luzon,

Visayas and Mindanao.

ON-GRID: refers to electrical systems composed of interconnected

transmission lines, distribution lines, substations , and related facilities for

the purpose of conveyance of bulk power on the grid of the

Philippines.

OFF-GRID: refers to electrical system not connected to the wires andrelated facilities of the on-grid systems of the Philippines.


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HOUSEHOLD: refers to a group of persons, generally but not necessarily bound

by ties of kinship, who sleep in the same dwelling unit and have common

arrangement for the preparation and consumption of food.

INDEPENDENT POWERPRODUCER (IPP): refers to private individuals or non-utility

corporations owning a bulk power generating facility for wholesale to others.

INSTALLED CAPACITY: refers to electric power for which a generating unit,

station or other electrical apparatus is rated under the specific condition

defined by the manufacturer in KW or MW.

LOAD FACTOR: refers to the ratio of the delivered Energy delivered during a

given period to the product of the maximum Demand and number of hours

during the same period.

LOCAL PRIVATE SUPPLY: an embedded generating plant, this could be from

a Renewable Energybased power facilities or other fuel type.

PENDING RESOURCES: resources that are fundamentally underway, although

not certain enough to be considered as committed resources, the probability

of their successful development is great enough to require their consideration

when determining the need for new resources. The success of these pending

resources can materially affect the need for other supply development.

POTENTIAL HOUSEHOLD CONNECTIONS: refer to the number of actual andprojected number of households in the franchise area based on the latest

figures from the National Statistics Office (NSO) or from data gathered by the

reporting DU.

POWERGENERATING FACILITIES: refers to the power generating plants owned

by the electric utility.

PRODUCTION: refers to the annual net energy produced by the power

generating facilities in KWh or MWh.

RENEWABLE ENERGY RESOURCES (RE Resources): as defined in Section 4(uu) of

Republic Act No. 9513 (Renewable Energy Act of 2008)

VOLTAGE LEVEL refers to the nominal voltage rating of the transmission or

distribution line.

WHEELING refers to a service provided by DU for the use of its distribution

facilities in transporting electric energy from one party to a third party.

CHAPTER IV


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Instructions for Accomplishing DOE-EPIMB Form-03-001rev1

(In order of Appearance)

1. Fill-up the General Information

2. Before you proceed , click Update Linkto capture the necessary data

3. Highlight the Filename Forecasted Data and workbook then click

Update Values button


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A. DDP-General Provisions

The accomplishment of DOE-EPIMB Form-03-001 shall be guided by the

following:

1. Name of Utility in Full: Name of DU as it appears in ERC/NEA/Congress

Franchise/ Authority/License No./R.A.#

2. ERC/NEA Authority/License No./R.A.#: The License or Authority Number of

the DU issued by ERC / NEA or Congress

3. Brief Description of Service/Franchise Area: Provide a brief description of

the service/franchise area of the DU. The description should cover at a

minimum the area size being served as well as the provinces and/ormunicipalities covered.

4. Grid: Name of the National Transmission Corporation (TransCo) or its

Concessionaire (National Grid Corporation of the Philippines) substation (if

bus-in) and/or transmission line (if cut-in) to which the reporting distribution

utility is connected.

5a.Description of the Methodology Used in Load Forecasting and Supply

Expansion Plan:

Demand Forecast Methodology

This narrative should document the electricity demand forecasting methods

and models used by the reporting DU in preparation of its DDP. Accordingly,

this description should include, but not be limited to:

a) Overview on the demand forecasting used;

b) Description of the key data inputs and outputs,

c) Sources of data;

d)

Descriptions of sector models including: model capabilities inforecasting electricity demand components and key forecast model

structural equations (econometrics, behavioral equations, identities,

aggregation);

e) Assumptions on the parameters used.

Supply Expansion Plan

This requires a brief narrative describing the general resource planning

approach taken by the reporting DU including:


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a) Key planning criteria which guided the preparation of the DDP;

b) Sources of data;

c) Scenarios and contingency plans considered (if any).

5b. Description Data Sources and Assumptions

In case econometric models are used, that is, electricity demand

patterns are explained by economic and demographic variables, the

reporting DU should indicate the models used in the projections. These

include the explanatory variables used such as economic and

demographic variables, energy price and other variables, if

applicable.

The reporting DU, particularly those with large service/franchise areas, should

provide sub-utility regional breakdowns of population and incomeprojections used in the development of the economic, demographic, or

energy forecasts.

Energy and Peak Demand Estimates

For estimates of the energy and peak demand reported in Items10aand 11a

respectively, describe fully the method used to generate forecast energy

and peak demand. If the method used in determining the peak demand

uses load factor" approach, indicate the load factor used and discuss if it

varies by year and/or by customer.

6 and 7.Number of Barangays and Households: In this section, the reporting

DU is required to show the number of barangays and households in its

franchise area. The DU shall then further indicate number of energized and

un-energized barangays and households, on a per on-grid and off-grid basis.

In the absence of NSO projection, the DU may forecast the number of

households using the average growth rate indicated in the latest census. The

number of residential consumers can be converted into number of

households by using a derived multiplying factor. The multiplying factor isequal to the number of households divided by the number of houses in the

area indicated in the latest NSO figures.

8. No. Of Customers: The number of customers, on an On-grid and Off-Grid

basis, is defined as the number of electrical connections with a provision of

an electric meter in its franchise area that is supplied with electric service

under a contract with a DU.

8a. In anticipation to the Open-Access the DU is required to indicate

number of customers with Demand indicated in this item. This Item is


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also associated with Annex-Open Access Customer. which requires

additional details.

The following shall guide the DU in filling-in items 8:

(1) On-grid DUs with no Off-grid system shall fill-in entries for On-grid

only.

(2) Off-grid DUs shall fill-in entries for Off-grid only,

(3) On-grid DUs with Off-grid system shall both fill-in entries for both On-

grid and Off-grid

9. No. Of Barangays and Sitios: Please refer to the data offered by the

National Statistics Office (NSO) to fill in the barangay number. Regarding

the number of sitios, if the official data is not available, the DU may rely

on its data gathered through ocular inspection or rapid appraisal in its

area in filling-in the number of sitios.

B. DDP-Demand

ENERGY REQUIREMENT

The segregation of energy sales and peak demand for the on-grid and off-

grid is intended to provide a better perspective on the energy requirement of

DUs.

The following shall guide the DU in filling-in item 10a:


only;

(2) Off-grid DUs shall fill-in entries for Off-grid only; and


grid and Off-grid.

10a. ELECTRICITY CONSUMPTION: The electricity consumption of the

reporting DU is defined as the sum of all sales to the customers in its franchise

includes supplied by other provider across all sectors, plus all unbilled energydelivered including its own consumption and its utility system losses.

DIRECT SALES TO CUSTOMERS: This entry represents the electricity sales

of the DUs to its residential, commercial, industrial, and other customers.

UTILITYS OWN USE: This entry represents the reporting DUs

consumption in its offices and other assets not categorized to any

rate classes and other distribution related facilities.

Utilitys Station Use: This entry represents the DUs consumption fordistribution related facilities.


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Utilitys System Losses: This entry represents the DUs overall system

loss. This could be defined as Net System Input less billed Customer

Sales or losses due to Technical and Non-technical losses.

TOTAL ELECTRICITY PURCHASED/GENERATED: This refers to the total energy

requirement of the utility secured or sourced from utility owned generators

and/or contracted supply.

PEAK DEMAND REQUIREMENT

The segregation of peak demand for the on-grid and off-grid is intended to

provide a better perspective on the peak demand requirement of DUs:

The following shall guide the DU in filling-in item 11a:


only;

(2) Off-grid DUs shall fill-in entries for Off-grid only; and


grid and Off-grid.

11a.

Peak Demand: The Peak Demand of the DU is defined as theaggregate of all coincident peak demandcontributing to direct sales by

customers across all sectors.

Direct Sales to Customers (Demand): The peak demand entered under

each customer class, Residential, Commercial, Industrial and Other

Customers, must be the demand occurring at the time of the DUs

coincident peak.

Utilitys Own Use: This entry represents the contribution to the coincident

peak caused by the DUs electricity demand for its own use (offices,housing and other non-distribution related facilities).

Utilitys Station Use: This entry represents the contribution to the

coincident peak caused by the DUs consumption in its distribution

related facilities.

Utilitys System Losses: This entry represents the contribution to the

coincident peak caused by the DUs overall system losses.

Peak Demand Requirement: refers to the coincident peak demandexperienced by the distribution utility, that is, the net of the sum of all


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coincident peak demand contributions of each class of customers, plus the

DUs own consumption, and system losses.

Time of Utilitys Peak: Time of the day at which the DUs coincident system

peak occurs during the reference year.

Month of Utilitys Peak: The month at which the DUs coincident system peak

occurs during the reference year.

11b. Demand-Side Management Programs: All load management programs

are geared at managing the coincident peak. The DU is required to

attach the outline of the DSM Program that the DU has been

implementing or planning to implement, if any.

12a. Utility Load Factor: This entry can be calculated by taking the Total

Electricity Purchased or Generated under Section 10a and dividing bythe quantity of the product of 8.76 times the Total Peak Demandunder

Section 11a.

12b. Monthly Load Data (Previous year) - Utilitys Peak Demand/Utilitys

Energy Consumption/Utilitys Load Factor: This entry requires the DUs

monthly coincident peak, energy consumption, and load factor.

C. DDP-Supply (Obligated)

This entry shall indicate quantities from existing contracts (contracts with

regulatory approval) entered into by the reporting DU and energy transacted

in the Wholesale Electricity Spot Market.

13a. Power Generating Facilities: The purpose of this section is to provide a

listing of all existing and operational generation facilities owned by the

reporting DU. For each generating plant there should be an identifying plant

name and unit number. In addition, the following information has to be

indicated:

Status - This refers to the status of the plant and categorize according to

the following: Operational and Non-operational.

Installed Gross Capacity (kW)- This is the Design Electrical Rating at which

the unit is designed to operate, or simply the name plate capacity.

Net Dependable Capacity (kW) This refers to the net dependable

capacity as measured at the substation bus (i.e. net of auxiliary station

service loads) or at metering points. For hydro plants, this refers to the

dependable capacity of the plant during dry season. Indicate in the


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submission the year or combination of years used as the basis for dry

season being referred to.

Net Production (MWH) This refers to the planned or actual annual net

energy output of the generating plant.

13b. Supply From NPC: This refers to the annual contracted demand (kW)

and contracted energy (MWh) from NPC to the reporting DU.

13c. Supply From NPCs Transition Supply Contract (TSC): This refers to the

annual contracted demand (kW) and contracted energy (MWh) from NPC

under the TSC of the reporting DU.

13d. Utility Contract Supply From Others: This refers to the annual contracted

demand (kW)/energy (MWh) from non-NPC generating facilities and those

transacted in the Wholesale Electricity Spot Market. Renewable Energy-based power facilities shall be indicated in this section.

13e. Local Private Supply: The purpose of this section is to identify and

quantify the amount of customer-owned or other self-generating capacity,

including Renewable Energy -based power facilities ,installed and utilized

within the DUs franchise area.

Installed Capacity in this section should reflect the total kW of all embedded

generators. Capacity Used for Own Use should reflect that portion of

Installed Capacity that is normally used to supply customer load at the timeof the DUs system peak.

Example: If a customer has two units of 500 kW generators and

operates one unit at maximum capacity to provide electric

supply while maintaining the other as back up, the Installed

Capacity is 1,000 kW and the Capacity for Own Use is 500 kW.

If a customer has a 500 kW generator but using it only as

standby, the Installed Capacity is 500 kW and the Capacity for

Own Use is zero.

Energy for Own Use is the total annual energy requirements in MWh of the

customer to be sourced from self-generating facility.

Energy Supply (surplus of embedded generator) is the maximum energy the

self-generating facility can supply to the DU annually.

13f. Total Supply: Total Capacityis the sum of the following:

1. Aggregate of all Dependable Capacity (kW) for each utility-owned

power generating facility listed in Section 13a.2. Contract Demand (kW) listed in Section 13b and 13c (Supply from


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NPC and NPC-TSC).

3. Aggregate of all the DUs firm capacity contracts from others as

listed in Section 13d.

4. Contracted Capacity from Local Private Supply listed in Section 13e.

Total Energyis the sum of the following:

1. Aggregate of Net Production (MWH) for each utility-owned power

generating facility listed in Section 13a.

2. Contracted Energy (MWH) listed in Section 13b and Section13c

(Supply from NPC and NPC-TSC).

3. Aggregate of all the DUs firm energy supply contracts from others

as listed in Section 13d.

4. Contracted Energy sourced from Local Private Supply(MWH) listed

in Section 13e.

13g Supply-Demand Surplus/ (Deficit): Capacity supply and demand is the

difference between the Capacity in Section 13f (Total Supply)and Section

11a (Total Peak Demand).

Energy supplyand demand is the difference between the Energyin Section

13f(Total Supply)and Section 10a (Total Electricity Purchased or Generated).

13h Owned Production Facilities: This item requires to list down the self-

generating facilities identified in Section 13a. There is a need to indicate theoperators name, if the operation and maintenance is entrusted to entity(ies)

other than the owner of the plant.

13i Supply from other sources: This item requires identifying and listing down

sources of power supply other than NPC or non-NPC Independent Power

Producers (IPPs), if there is any.

13j Wheeling Service: This is an indicator whether the reporting DU is

providing wheeling service.

13k Customers of Wheeling Service: If yes in 13j, this item requires the DU to list

down the customers paying wheeling fees to the DUs and other information

such us power and energy to be wheeled and contract terms.

Assuming the reporting DU offers wheeling service; the electricity sold from

the generation company to the customer is not counted as direct sales of the

distribution utility. However, the DU is required to clarify the amount of the

wheeling service in this form.

D. DDP-Supply Forecast (Un-obligated)


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This entry (items 14a to 14i) is similar to Item 13 but shall only indicate, among

others, quantities from yet to be entered supply contracts from committed

generating facilities, contracts that still need regulatory approval, from

expected generation output of DU owned generation facility under

construction, and energy to be transacted in the Wholesale Electricity Spot

Market.

Renewable Energy-based power facilities shall be indicated in this section.

The impact of these resources on overall supply adequacy is great enough

that the DOE considers these resources when determining the need for other

resource development. At the start of a PDP process, a pool of pending

resources will be identified. The pool of pending resources may include but

not limited to the following: private power resource development and

Renewable energy-based resources.

E. DDP-DDP

The purpose of this section is to indicate the total amount of existing and to

be installed sub-transmission, distribution, and substation facilities.

15a and 15c. Distribution / Sub-transmission Circuit-Kilometers (Acquisition

and Expansion): Provide the cumulative historical data of distribution

feeders, in circuit kilometers, and the yearly forecasted data of distributionand/or sub-transmission lines for each of the voltage levels listed. The circuit-

kilometers are determined by measuring the total length of distribution/sub-

transmission line in kilometers for each voltage levels listed and for each

system.

This should also include the required connection facilities for Renewable

Energy-based power facilities as required in Section 11 of RA 9513.

15b and 15d. Distribution/ Sub-transmission Line (Replacement and

Rehabilitation): Provide the cumulative historical and yearly forecasted dataof the rehabilitation result and plan for the distribution and sub-transmission

line in circuit kilometers in accordance with each of the voltage levels listed.

16a. Substation Capacity (Additional): For each size of substation transformer

as listed, provide the cumulative historical data (the total number of

transformers and cumulative MVA capacity) to be retained and the

forecasted data should be on a yearly basis.

16b. Substation Capacity (Retirement): For each size of substation transformer

as listed, provide the historical and forecasted data on a yearly basis theretirement of substation.


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17. Reactive Power Compensation: The purpose of this section is to indicate

the types and sizes of reactive (var) sources installed/planned in order to

reduce the amount of reactive power transported over the lines or improve

the DUs power factor.

18. Capital Expenditures: The purpose of this section is to show the total

capital expenditures required each year for the construction and/or

acquisition of Distribution lines, Sub-transmission lines, and additional

substation capacity to energize barangays or sitios, improve power quality,

increase system reliability, and the Electrification Cost to be incurred in all

other projects (rehabilitation, additions, logistics support, institutional etc.)

including the utilitys best estimate of both the local and foreign components.

All amounts should be expressed in peso (Million) amounts.

F. DDP-Other

19. Information on Distribution Impact Study:

The reporting DU is required to indicate the information necessary and used in

the technical set of studies which were used to assess the possible effect of a

proposed expansion, reinforcement, or modification of its distribution system.

This requirement also refers to Section 11 of the Renewable Energy Act of2008.

20. Supply Highlights

The reporting DU shall indicate activities that will lead to the growth of peak

and energy requirements (i.e. expected entry of large load customer), any

related development to the distribution system that will result to improvement

in power quality and reliability, or supply contracts that will be entered by DU

to meet growth in energy requirement.

G. Annexes

ANNEX 1 - Demand Off-Grid:

In connection to items 10a and 11a, this section shall be filled-in to indicate

current service provider, historical peak demand, and projected peak

demand of every off-grid system within the reporting DUs franchise.

This section should be filled-in on a per Off-grid system basis.


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ANNEX 2 - POTENTIAL OPEN-ACCESS CUSTOMERS:

In preparation for the open-access, the lowest recorded peak demand,

highest recorded peak demand, and previous years electricity sales of

customers with load of 750kW and above but less than 1MW and with load of

1MW and above, shall be provided.

This section is associated to item 8a.

ANNEX 3 - POTENTIAL HOUSEHOLDS:

In line with the Policy of the State of total electrification of the country, this

section shall determine yet to be energized household in the reporting DUs

franchise.

This section shall be filled-in on a per Municipality basis and per Barangay

level.

Click DDP - Summary

This worksheet is already linked, the EC will just have to input the Supply

/ Demand Highlights In the blue colored cell. Then click Save and click

Back


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Click Save, On this button the EC must execute to save and wait for

the process to complete then press Exit.

POWER DEVELOPMENT PLAN FRAMEWORK


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IV. FINANCIAL FILE


Password "biennialicpm" then

Click Submit

2. Fill up the General Information

Select EC Name, NEA

Categorization and RSEC-WR

Group on the Drop-down List and click Toggle Switch, then Click Save

3. Click Updates Linkto update the necessary file

4. Highlight the filename Forecasted Data and Long-Term Development

Planworkbooks then click Updates Valuesbutton.


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5. Click Income StatementButton, Input Area (white cells) - Input the latest

actual data of the EC 2012 Income Statement (audited, if any) , in Php

000

6. Click Balance Sheet Button, Input Area (white cells) - Input the latest

actual data of the EC 2012 Income Statement (audited, if any)


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ADMINISTRATION

7.

Documents

Biennial ICPM Manual