biennial icpm manual
TRANSCRIPT
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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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BIENNIAL INTEGRATED COMPUTERIZED PLANNING MODEL (ICPM)NATIONAL
ELECTRIFICATION
ADMINISTRATION
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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BIENNIAL INTEGRATED COMPUTERIZED PLANNING MODEL (ICPM)NATIONAL
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ADMINISTRATION
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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BIENNIAL INTEGRATED COMPUTERIZED PLANNING MODEL (ICPM)NATIONAL
ELECTRIFICATION
ADMINISTRATION
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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ADMINISTRATION
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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ADMINISTRATION
II. LONG-TERM DEVELOPMENT PLAN FILE
1. Input you Username and
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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ADMINISTRATION
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:
(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; and
(3) On-grid DUs with Off-grid system shall both fill-in entries for both On-
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:
(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; and
(3) On-grid DUs with Off-grid system shall both fill-in entries for both On-
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
1. Input you Username and
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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7.