· pdf fileinstalled q1000 meter at pagat substation for p-321; verified pts/cts for pending...
Post on 07-Mar-2018
215 Views
Preview:
TRANSCRIPT
Page 1 of 8 6/15/2010
APPENDIX A
Progress Reporting for Dec 09 – May 2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
1 Accurate metering and billing of the U.S. Navy
1.1 Process Ongoing
Navy account set in Utiligy for electronic
meters (Q220 and Q1000) at all Navy
metering points.
Actual billing of Navy is reviewed by GPA prior to issuing to Navy.
Manual billing issued until Utiligy set-up is finalized. Consumption, reads and
billings from March 2007 through December 2009 have been entered in Utiligy.
Starting October 31st, GPA has started using handheld devices to read the Navy
quantum meters for upload to Utiligy.
1.2 Pending
Exploring the feasibility of aggregate
reading No changes during the period of Dec 2009 through May 2010
Currently unavailable; working with software developer; will not be available until
the next release.
Harmon Substation & Tanguisson Substation WAN link ordered to provide
capability of remote Navy Metering
2 Accurate metering and billing of civilian loads
2.1 Process Ongoing
Meter Task Force (MTFC) continues to
oversee, assess, and issue recommendations
for QA/QC of metering and billing
accuracy
System Losses Report Data
Dec 2009 – May 2010
o Three-Phase meter accounts (MTF)
Accounts investigated with meter discrepancies found and
corrected: 4
Accounts investigated with no meter discrepancy: 116
*No Three-Phase meter accounts (MTF) data reported for the months of Feb & April 2010
o Ongoing Single & Three phase meter field investigations (MFI)
Accounts with meter discrepancies found and corrected: 419
Accounts with no meter discrepancy: 3,048
2.2
Process Ongoing
Customer service continuing to resolve
issues for hard to read or inaccessible
meters
Hard to read or inaccessible meters (unsafe conditions, gate lock, vicious dog, etc.)
Dec 2009: 264 accounts
Jan 2010: 196 accounts
Feb 2010: 199 accounts
Mar 2010: 217 accounts
April 2010: 206 accounts
May 2010: 252 accounts
GPA coordinating with Customers for actual readings on a monthly basis after
billings estimated three times their average consumption. Adjustments are made
based on actual/verified readings and consumptions.
Page 2 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
Process Ongoing
Customer service continuing to resolve
issues for hard to read or inaccessible
meters
GPA now notifies customers through system generated letters. 1st Notice given
informs the customer to coordinate for a verified reading or apply for relocation of
meter within 10 days. Final notice given to inform the customer that service can be
terminated.
First and final notices mailed out to customers with inaccessible meters:
o Dec 09: 8 accounts
o Jan 10: 48 accounts
o Feb 10: 75 accounts
o Mar 10: 158 accounts
o Apr 10: 43 accounts
o May 10: 41 accounts
Tracking of letters sent and acknowledgement of customers’ response will be done
via cat codes in the service connection window of Utiligy.
2.3
Process Ongoing
Identify all zero consumption billings and
perform required field investigations
For Dec 2009 thru May 2010, 653 accounts identified with zero consumption and
94 accounts have been investigated and processed for corrective action they include:
o 73 accounts revealed vacant units (no load/minimal consumption)
o 3 accounts have field testing/pending investigation
o 17 accounts have meter change-outs; pending backbilling
o 1 account have pending work clearances/meter removed
A report is created to identify age of the meters servicing these addresses for
possible testing whether they are defective, etc. and also to monitor previous
consumption history.
3 Systematic analysis of billing accounts for possible outliers
3.1 Process Ongoing
Documentation for systematic billing
analysis Continuous
o Descriptive statistics are performed to identify customer accounts for
further investigations.
o Analysis/refinements addressed on a monthly basis as problems are
encountered.
o Both the reading exception and billing exception reports are being
reviewed and scrutinized for each billing cycle monthly. These reports
indicate all the possible reading and billing exception that warrants review
and attention.
3.2 Process Ongoing
Monitoring of reading exception reports in
Utiligy system Continuous - reading exception reports are verified for accuracy and statistics of
reading exception errors are tracked by Accounting. Any item requiring service
order or investigations are being routinely communicated to Customer Service.
3.3 Process Ongoing Additional reports generated monthly in
Utiligy system to assist in billing analysis Continuous – reports are generated monthly to assist in billing analysis
4 Accurate Monitoring, Measurement and Reporting of System Losses
Page 3 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
4.1 Process Ongoing
Civilian load recovery reported by the
MTFC monthly on a system losses report
Dec 2009
o Single & Three phase Meter Field Investigations
11 accounts w/adjustments for backbilling
Revenue recovery: $7,134.38
kWh recovery: 34,211
Jan 2010
o Single & Three phase Meter Field Investigations
12 accounts w/adjustment for backbilling
Revenue recovery: $1,221.73
kWh recovery: 5994
*Pending revenue/kWh recovery reported for the Months of Feb-May 2010
4.2
Identify present metering discrepancies December 2009:
Meter Discrepancies: 97
Meter investigation MFI: 348
Meter investigation INV: 23
Meter change outs: 61
January 2010:
Meter Discrepancies: 32
Meter investigation MFI: 151
Meter investigation INV: 26
Meter change outs: 38
Page 4 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
Process Ongoing February 2010:
Meter Discrepancies: 126
Meter investigations MFI: 180
Meter investigation INV:82
Meter change outs: 147
March 2010:
Meter Discrepancies:123
Meter investigation MFI: 259
Meter investigation INV: 57
Meter change outs: 161
April 2010:
Meter Discrepancies: 104
Meter investigation MFI: 273
Meter investigation INV: 56
Meter change outs: 141
May 2010:
Meter Discrepancies: 42
Meter investigation MFI: 125
Meter investigation INV: 79
Meter change outs: 107
Performed load analysis and on site testing of meters.
Ongoing BPL prepaid meter project to install meters. Coordinated with
Engineering and contractors installed 15 each meter with data concentrators for pilot
project. Tested new echelon meters for installation.
A total of 80 meter numbers were updated in Utiligy for accountability.
Ongoing preventive maintenance three phase large consumers.
4.3 Process Ongoing
Procure equipment & systems No equipment & systems procured from Dec 09 – May 2010
4.4
Process Ongoing
Replace, install, and upgrade substation
metering reporting systems December 2009:
Installed Q1000 meter at Pagat Substation for P-321; verified PTs/CTs for
pending energization of feeder.
February 2010:
Refurbished Mobile Sub metering and hardware coordinated with Substation
crew. Location: Dededo Sub and Tumon Substation.14MVA 30MVA.
Ongoing Substation dial up attempt via phone line communication with
Substation Q1000 and Sel-734 metering. Harmon Substation and Pagat
Substation.
Page 5 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
5 Identification of unlisted electric energy consumers
5.1
Process Ongoing
Process in place to identify and minimize
occurrences in Unlisted consuming meters.
Various reports are generated to identify
unlisted energy consumers (i.e., exception,
UNLISTEDMTR report for meter readings
that were not captured in Utiligy and
therefore ran after each upload).
Dec 2009
RPS conducted 3 inspections on meter listed in the consuming listed meter report.
Of that, 1 meter was found with termination seals (not consuming), 1 meter was in
use and removed for no active account, and 1 meter had an account but was not
billed. Information was forwarded to Customer Service for billing.
Jan - Mar 2010
RPS conducted 5 inspections on meters listed in the consuming unlisted report.
Investigations revealed that 1 meter is a sub meter (privately owned); 2 meters
have active accounts and are being billed; 1 meter was in use without an account
and the meter was removed; 1 meter has an active account but was not billed.
Customer Service was provided the meter information to initiate billing.
RPS investigated 30 random meters listed in the billed accounts with minimum
billing report. Of that, 18 locations were confirmed as vacant, 7 were not in use, 1
meter had terminated sealing devices still intact, and 4 were in use by new tenants.
The terminated meter information was forwarded to Customer Service for proper
termination.
April – May 2010
RPS conducted 8 inspections on meter listed in the consuming unlisted report.
Investigations revealed that 1 meter is a sub meter (privately owned), 1 had
termination seals, 1 was registering but did not have an account (RPS removed
meter), 2 had active accounts but were not billed, 2 meters were changed out but
not processed, and 1 was not consuming (reading error). Information on the
terminated meter, change outs and the active accounts not billed were forwarded
to Customer Service for appropriate action.
RPS also investigated 23 meters listed in the billed accounts with minimum billing
report. Of that number, 19 units/houses were vacant, 2 (temp) services were not in
use, and 2 meters were registering with new occupants/tenants.
5.2
Process Ongoing
Tampering and illegal connections
investigated and documented through
GPA Revenue Protection Section, Internal
Audit Section.
Dec 2009
RPS conducted 10 meter tampering/theft of service field investigations. Of that,
6 were confirmed violations they include: 1 meter was found with disconnect seal,
power in use, 1 was swapped (both meters retrieved), 1 meter was inverted
(upside down), and 3 direct hook-ups were found on the service
wire. All 6 cases were reported to the proper authorities and services were
isolated/terminated.
Page 6 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
Process Ongoing
RPS also conducted 19 meter checks: 13 meters were found with seal cuts/corroded,
new white seals and/or lock straps were installed; 1 defective meter was changed
out and information forwarded to Customer Service for back billing; 1 meter
found terminated and not in use, removed and returned to Meter Shop for evaluation;
4 meter systems were inspected but no discrepancies were found.
Jan – Mar 2010
RPS conducted 21 reported/suspected meter tampering investigations. Of that, 12
were cited for confirmed meter tampering/theft of service based on the following
discoveries: 1 inverted (upside down) meter, 6 disconnection/termination seals cut/
removed – power on, 2 unauthorized meter removals, 1 stolen meter, 1 direct hook
up to service line, and 1 reported stolen conductors (approx. 250ft). The remaining
9 were determined not to be tampered: 2 damaged meters reported and was not
compromised, 1 alleged meter swapping (assigned meter registering with sealing
devices still intact), 1 meter seen with disconnection (green) seal, 1 possible
unauthorized removal, 1 meter reported missing, and 3 reported possible tampering
yielding no discrepancies upon investigation.
April - May 2009
RPS conducted 14 reported/suspected tampering investigations. Of that, 8 were cited
as confirmed violations based on the following discoveries: 3 vandalized meters,
1 jumpered meter socket, 1 terminated meter registering found with potential link
opened, 2 disconnected/terminated seals removed (power on) and 1 meter with
damaged strap and disconnection seal remaining, 6 were determined not to be
tampered: 1 inverted (upside down) meter was without load side wirings – removed
and socket secured, 2 meters found on the ground (fell out of meter socket – one
changed out, the other is terminated), 1 reported meter missing was later determined
to be an Emergency Work Clearance, 1 possible direct hook-up was determined to
be on the load side in panel box, and 1 possible meter tampering was found with
a shorted meter box, given Emergency Work Clearance.
RPS also conducted 5 meter checks: 1 meter with a corroded seal (changed), 2
meters changed out (defective), 2 revisits to previously tampered/changed out sites
(no discrepancies found).
6 Power system design and procurement guides considering optimization of system costs and losses
6.1 Process Ongoing
Prepare conductor economics selection
and evaluation guidelines Conductor sizing guidelines based on voltage drop prepared for single-phase loads is
completed. Three-phase guidelines are being finalized. Analysis of existing system
will be conducted through the Medium Range Plan completed in April 2010.
Page 7 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
6.2 Process Ongoing
Stock appropriate transformers Engineering will identify oversized transformers to be changed out. Analysis will
commence after metering data is mapped and modeled to determine actual
consumption from CIS data. 25,000 of 46,000 meters have been updated and mapped.
7 Metering assessment and correction of customer power factor
7.1 Process Ongoing
Evaluating large demand customers to
define magnitude of power factor problem. AMX software is still resolving issues on 5 individual accounts out of 176 accounts in
cycle 23 as of 6/4/2010. GPA has not received instructions to apply the changes from
DV to the PD environment.
AMX software developer has completed the power factor program based on the
KVAH reads.
7.2 Process Ongoing
Evaluating economics of power factor
improvement Evaluation of economics of power factor improvement completed. Engineering will
order capacitors as part of the Distribution capital improvement project program in
accordance with the Medium Range Plan completed in April 2010.
7.3 52% Completed
File new rate – cost of service study
Developed sample design for the load study.
Coordinate with Guam PUC consultants on objectives and design.
Reviewing meter types and meter software; obtain quotes on standard and telecom-
enabled meters for study.
Addressing questions from Bruce Oliver.
T & D reviewing form factor information.
Load Study Meters Delivered
Preparing Maps to Sample locations
Coordinated with GPA Meter Shop for Meter Installation Procedures
Creating Process QMP
Finalizing Sample Data
Removing Disconnected Accounts
Removing Accounts with Inaccessible or Difficult to Read
Troubleshoot and Installed 198 Load Study Meters
Downloaded data for 198 Load Study Meters for October, November and Dec. 2009.
Downloaded data for 198 Load Study Meters for Jan, Feb, Mar & April 2010.
8 Cost effective reactive power compensation
8.1 94 % Completed
Perform long range transmission planning
study
Developed transmission study report template draft.
Provided on-site power flow analysis software training.
Developed preliminary transmission planning criteria.
Finalized load forecast to include civilian and military projects.
Consultant reviewing power flow models.
Finalized power flow models for analysis.
Revising and updating load forecasts
Including wind and non-firm power impacts into study.
Completed revision of load models to account for new JGPO input and updated load
forecasts.
Page 8 of 8 6/15/2010
KEY MANAGEMENT
OBJECTIVE TASK DESCRIPTION STATUS
Completed validation of Spatial forecast including new information on Military loads.
Updated PSLF Power Flow model based on new spatial forecast.
Re-run power flows for 2010 through 2020 and updated figures.
Worked with RW Beck consultant to analyze power flows for 2010 through 2020.
Completed draft of Transmission Study document.
8.2 Completed Connectivity model of distribution circuit
and building load model. GPA Engineering has completed modeling and analysis of the distribution system.
8.3 Completed Perform medium range distribution
planning study. Medium Range Plan completed in April 2010. See attached report
8.4 Progress Ongoing
Procure and install distribution capacitors
Engineering will order capacitors as part of the Distribution capital improvement
Project program in accordance with the Medium Range Plan completed in April
2010.
9 Quality Systems Design & Implementation
9.1 Documentation including supporting
documents is regularly updated & maintained Documents updated and submitted quarterly.
Prepared by: 1)istrihuiion Engineering
DISTRIBUTION ANALYSIS2010-2015
SubmittedApril 26, 2010
RO, BOX 2977 HAGATNA, GUAM u.S.A. 96932-2977 Tel. No: 648-3011 Fax No: 648-3167
Guam Power Authority Distribution Analysis 2010 — 2015
AcknowledgementsThe Guam Power Authority Distribution Analysis Report was a cooperative effort of the EngineeringDivision. This project was led by the Distribution Engineering group to study, manage, and improve thedistribution primary system. Immediate and potential needs were examined and solutions were renderedto meet those needs. The previous distribution report was completed in 1992. Since the 1992 report,resources have been diverted from this work and much has been lost in system asset maintenance,modeling and analysis experience, and process enforcement. For this reason, the generation of this 2010report involved a painstaking process to capture existing system as-builts and characteristics, map andmodel accurate data, analyze current system peifonnance, and consider improvement scenarios tomaximize peiformance and plan for future growth. Therefore, the Distribution Engineering groupgratefully acknowledges the contributions of engineers and technicians and the support of theirsupervisors and managers that have made this report possible.
Project Lead:
ward A. K. Cruz, Engineer II Loti. amacho, Engineer I
Data collection, Mapping and Field verification:
Ariel D. Mata, Engineer I (Distribution Engineering)
Ryan 3. S. Topasna, Engineering Technician II (Distribution Engineering)
Timothy C.S. Muna, Engineering Technician II (Distribution Engineering)
Luke M. Ogo, Engineering Technician II (Distribution Engineering)
Arthur M. Manglona, Construction Inspector Ill (Distribution Engineering)
David A. Delgado, Construction Inspector III (Distribution Engineering)
Noel C. Gulac, Engineering Technician II (Substation/Transmission Engineering)
August Guerrero, Chief Dispatcher PSCC
T&D Meter Relay Division
System Modeling and Analytical Engineering Analysis:
Irwin B. Loyola, P.E., Special Projects Engineer (Substation/Transmission Engineering)
Nanette T. Guerrero, Engineer III (Customer Service Engineering)
Edward A. K. Cruz, Engineer II (Distribution Engineering)
Louis C. Camacho, Engineer I (Distribution Engineering)
Supervisor
‘Melmda R. Camacho, P.E., Manager of Engineermg
—1—
Guam Power Authority Distribution Analysis 2010 — 2015
TABLE OF CONTENTS
1.0 EXECUTWE SUMMARY 5
1.1 Objective 5
1.2 Purpose 5
1.3 Scope 5
1.4 Major Findings 5
1.5 Report Organization 6
2.0 DISTRIBUTION PLANNING CRITERIA 7
2.1 Voltage 7
2.2 Loading 7
2.3 Unbalance 7
3.0 DATA ACQUISITION & MODELING 8
3.1 Methods ofData Acquisition 8
3.1.1 QuantumMeter 83.1.2 EnergyLogger 8
3.2 Data 8
3.3 Modeling 8
3.3.1 Historical Modeling 83.3.2 SynerGEE 93.3.3 Load Allocation Method Verification 9
3.4 Demand Factor 10
3.5 Load Factor 12
3.6 Loss Factor 13
3.7 Annual kWh Losses 15
4.0 CAPITAL IMPROVEMENT PROJECTS 16
4.1 Cost Benefits 16
4.2 Load Transfers 16
4.2.1 Permanent to Address Overloads 164.2.2 Temporary to Address Back-Feeding 17
-2-
Guam Power Authority Distribution Analysis 2010 — 2015
4.3 Balance Improvement 18
4.4 Capacitor Placement 19
4.5 Balance Improvement & Capacitor Placement 19
4.6 Re-conductoring 19
4.7 Balance Improvement & Re-conductoring 20
4.8 Balance Improvement, Re-conductoring, & Capacitor Placement 20
4.9 Project Priorities 20
5.0 LOAD FORECASTING 22
6.0 5-YEAR PLANNED DISTRIBUTION CIP LIST 24
7.0 SYSTEM SUMMARY AND CONCLUSION 25
7.1 Agana Substation 26
7.2 Andersen Substation 28
7.3 Anigua Substation 29
7.4 Apra Substation 31
7.5 Barrigada Substation 33
7.6 Dededo Substation 35
7.7 GAA Substation 37
7.8 Harmon Substation 38
7.9 Macheche Substation 39
7.10 Pagat Substation 41
7.11 Piti Substation 42
7.12 Pulantat Substation 43
7.13 San Vitores Substation 45
7.14 Talofofo Substation 47
7.15 Tamuning Substation 49
7.16 Tumon Substation 52
7.17 Umatac Substation 55
7.18 Yigo Substation 56
-3-
Guam Power Authority Distribution Analysis 2010 — 2015
TABLE OF APPENDICES
APPENDIX A — Loss Factor Empirical Formula Calculation 58
APPENDIX B — Feeder Loss and Load Factors 60
APPENDIX C — Metered data for SynerGEE Simulations 62
APPENDIX D — Initial Load Flow Analysis 64
APPENDIX E — Load Transfer 66
APPENDIX F — Balance Improvement 67
APPENDIX G — Capacitor Placement 69
APPENDIX H — Balance Improvement and Capacitor Placement 71
APPENDIX I — Re-conductoring 73
APPENDIX J — Balance Improvement & Re-conductoring 75
APPENDIX K — Balance Improvement, Re-conductoring, & Capacitor Placement 77
APPENDIX L — Improvements 79
APPENDIX M - T&D Costs 81
APPENDIX N — Backfeeding 82
-4-
Guam Power Authority Distribution Analysis 2010 — 2015
1.0 EXECUTIVE SUMMARY
1.1 Objective
This study of the Guam Power Authority’s (GPA) island-wide distribution system was conducted
to evaluate the capability and performance of the primary distribution system from the present
time through fiscal year 2015. Analysis of the system’s existing condition provided the base case
to compare with the American National Standards Institute (ANSI) C84. 1-2006 for voltage
delivery and with the Distribution Planning Criteria 330.1 rev.0 for 75% loading of lines and
transformers, and unity power factor. Corrections to the system were developed to meet these
criteria.
1.2 Purpose
The study’s two fold purpose is to evaluate the existing condition of GPA’s distribution system
and recommend changes that enable the system to meet the Distribution Planning Criteria and
ANSI C84.1-2006 for voltage delivery. The intent is to present an accurate, detailed picture of
the system’s performance and capability. Shortcomings of the system are identified, and then
preferred and alternate solutions are prescribed to meet current and future needs. Justification for
each preferred solution over alternatives is given.
1.3 Scope
The scope of this report covers voltage, loading, and unbalance on the 13.8 kV distribution
system. The time span covers FY 2010 through FY 2015. Improvements to the system are
addressed along with construction costs and kWh loss savings estimates.
1.4 Major Findings
Major results of the study include the following. P-087, P-33 1, P-242, and P-250 are over 75%
loaded. P-087 is loaded at 82% of the normal conductor rating. P-33 1 is loaded at 83% of the
normal conductor rating. P-242 is loaded at 77% of the normal conductor rating. P-250 is loaded
at 81% of the normal conductor rating.
P-087, P-330, P-250, and P-323 have voltages lower than 0.95 pu. P-087 has a minimum voltage
of 0.92 pu. P-330 has a minimum voltage of 0.95 pu. P-250 has a minimum voltage of 0.95 Pu.
P-323 has a minimum voltage of 0.95 pu. P-087 has a voltage unbalance of 3.36% which is
greater than the 3% requirement according to ANSI C84. 1-2006.
-5-
Guam Power Authority Distribution Analysis 2010 — 2015
Loading issues are addressed and recommendations are listed in Section 4.2.1. Appendix L
provides a list of feeders with voltage and/or loading violations and the recommended
improvements to meet the Distribution Planning Criteria and ANSI C84. 1-2006.
1.5 Report Organization
The report contains sections in the following order: Distribution Planning Criteria, Data
Acquisition & Modeling, Capital Improvement Projects (CIPs), Load Forecasting, 5 Year
Planned Distribution CIP List, and System Summary and Conclusions.
The section on Distribution Planning Criteria provides the basis for the analysis of the distribution
system. The criterion sets the limits for system corrections. The Data Acquisition & Modeling
section outlines the previous and current methods used to collect, analyze, and normalize data.
All the calculations for Load, Loss, and Demand factor are listed. In the Capital Improvement
Projects section, load transfers were assessed, and benefit cost analyses were conducted for
balance improvement, capacitor placement, re-conductoring, and combinations of the three. The
Load Forecasting section explains the methods used to determine the impact of known future
loads to the system. The 5-Year Planned Distribution CIP List provides a prioritized listing of
planned capital improvement projects. The System Summary and Conclusions section reports on
existing conditions and recommendations itemized by substation for all distribution feeders.
Finally, future planning and analysis goals are discussed.
The loss factor validation spreadsheet is found in Appendix A. Loss and load factors for all the
feeders are listed in Appendix B. Appendix C lists the substation feeder peak metered data used
to run the SynerGEE simulations. Initial feeder load flow results referenced in support of
recommended CIPs are found in Appendix D. Appendices E, F, G, H, I, J, and K provide tables
for loss reduction, cost, and savings from recommended load transfers, re-phasing, capacitor
additions, re-conductoring, as well as combinations of said recommendations. Appendix L
provides a before and after comparison of the electrical characteristics of each feeder after
modeling the recommended CIPs. Construction costs estimated for the different CIPs are listed
in Appendix M. Back-feeding capabilities are listed in Appendix N.
-6-
Guam Power Authority Distribution Analysis 2010 — 2015
2.0 DISTRIBUTION PLANNING CRITERIA
Feeder voltage, loading, and unbalance were analyzed against the Distribution Planning Criteria
and ANSI C84. 1-2006 to determine system improvements necessary to meet required standards
of performance.
2.1 Voltage
The first factor addresses the adequacy of GPA’s voltage delivery to customers. The criterion
used is based on ANSI C84. 1-2006 which requires the voltage level at the point of customer
connection to be within ±5% of nominal voltage (0.95 Pu and 1.05 pu). Furthermore, the primary
distribution line voltages shall be within +5% and -2.5% of nominal voltage (1.05 Pu and 0.975
pu). Per-unit or pu represents the normalized value of the physical voltage calculated as the ratio
of the actual voltage to a chosen base. The base used for this study is 13.8 kV. Therefore, the
limits of 0.975 Pu and 1.05 Pu correspond to the physical voltage values of 13.46 kV and 14.49
kV respectively.
2.2 Loading
The second factor addresses the loading limits of the feeder lines and substation transformers.
These limits are set at 75% of the maximum rating of the line as specified in the GPA
Distribution Planning Criteria.
2.3 Unbalance
The third factor addresses imbalances on feeders. ANSI C84. 1-2006 requires electric supply
systems to be designed and operated with a maximum voltage unbalance of 3%.
Voltage unbalance on the system has a serious affect on the quality of power delivery to 3-phase
customers. Voltage unbalances will cause heat generation in 3-phase motors reducing efficiency,
degrading insulation, and leading to equipment failure. Current and load imbalances are reviewed
in terms of how these imbalances impact voltage unbalance.
-7-
Guam Power Authority Distribution Analysis 2010 — 2015
3.0 DATA ACQUISITION & MODELING
3.1 Methods ofData Acquisition
Data for distribution feeder modeling was obtained from Quantum meters and energy loggers
installed at the low voltage side (13.8kv) of the substation transformers. 31 feeders had
information obtained from Quantum meters and 32 feeders had information from energy loggers.
3.1.1 Quantum Meter
Data from 2007 to 2009 were obtained from 31 Quantum meters. For the first time in distribution
analysis, real power, reactive power, apparent power, voltage and current values are available at
15 minute intervals. This has had a significant impact on the quality of analysis results and a
considerable improvement over previous GPA distribution studies. Quantum meter data is
representative of feeder behavior and was used to obtain load factor and loss factor.
3.1.2 Energy Logger
Data collected from energy loggers for 32 feeders include voltage, amperage, real power, reactive
power, apparent power, and power factor. Energy logger data was limited to 2 weeks of data at
15 minute intervals. The use of the energy loggers is similar to previous data collection processes
and therefore presents the same limitations. However, the determination of load and loss factors
provides the means to use this data in support of distribution analysis.
3.2 Data
The maximum loading of each feeder was obtained from the metered data. Once the date and
time of maximum loading were determined, the loading was validated and outliers attributed to
back feeding and faults were eliminated. The resulting maximum load day of a feeder was the
24-hour data range used for the analysis of this report. To determine the losses over a one year
period, a loss factor was derived using an empirical formula developed from the Quantum data.
3.3 Modeling
3.3.1 Historical Modeling
DPAS was the distribution modeling software utilized by GPA prior to this study. DPAS
modeling was based on a two week loading interval directly measured using the Dranetz Energy
Recorder. In addition, load was allocated to transformer loads using actual but non-coincident
-8-
Guam Power Authority Distribution Analysis 2010 — 2015
kWh values. Peak loading of a feeder was limited to the peak of the selected interval and time of
year was arbitrarily chosen.
3.3.2 SynerGEE
SynerGEE was the modeling software utilized for this report. Loading limits were calculated
from metered data taken at the substation transfonners and distribution feeders. These limits
were based on the maximum ampacity rating of the conductors at the substation. Voltage
regulation and unbalances were determined from system modeling using SynerGEE software.
Line type, line length, breakers, fuses, switches, capacitor banks, and connected KVA of the
13.8kV system were modeled geographically. The program allocated loads throughout the
system with respect to the per-phase metered data at the substation. This metered data is shown
in Appendix C. Load flow analyses were conducted from which data regarding voltage, loading,
and unbalances were obtained to establish the system base case.
Feeder loss improvements were considered to support economic analysis of capital improvement
projects. The losses were calculated from kW losses provided by SynerGEE. Losses were used
to analyze the cost effectiveness of CIP recommendations.
3.3.3 Load Allocation Method Verification
For verification of model results, three feeders were selected to compare kWh allocation to kVA
allocation. kVA allocation uses the connected kVA of the transformers and the feeder loading to
allocate load throughout the system. kWh allocation is a more precise method of allocation that
uses the kWh connected values at each transformer and allocates loads with respect to their
contributions and the feeder peak loading at the substation.
P-244 kWh vs. kVA allocation
Actual metered data collected for every meter serviced by P-244 for the month of November
2009 was compared to the metered max loading taken on November 13, 2009. Non metered
loads were also considered. The maximum difference between the two allocation methods for
phase voltage was 3% with the maximum current difference of 7 amps.
P-332 and P-400 kWh vs. kVA allocation
Average kWh per residential customer taken from the GPA Accrued revenue FY 2009 report is
32.6 kWh per day. Allocation was performed by using this average kWh per day along with the
-9-
Guam Power Authority Distribution Analysis 2010—2015
number of customers per transformer and the connected street light kWh to determine loading for
single phase residential customers. For 3-phase and commercial customers, actual billing
consumption was taken to determine loading. The by-phase results for P-332 showed a
maximum voltage difference of 5% and a maximum current difference of 7 amps. P-400 showed
a maximum voltage difference of 1% and a maximum current difference of 6 amps.
Based on this analysis, kVA allocation is sufficient for primary system modeling to address the
goals of this report. The differences between the various methods of allocation were not
considerable enough to affect the overall behavior of the feeders. kWh allocation will be
addressed in future reports after ongoing projects are completed and a more efficient method of
data collection and monitoring is in place.
3.4 Demand Factor
The equation for demand factor is defined as
DF= maximum demand
total connected demand
Table 1 provides demand factors for the feeders with Quantum data. Table 2 provides the
demand factors for the feeders with Energy Logger data.
-10-
c.-.1 I
H
1j
II
II
II
II
II
II
II
II
II
II
II
II
II
ICD
cJ
tJtJ
t’J
tJ.1
L’)
k)
t’)
t’.)
Lt’
J(
L.1
.14.
tJV
iV
iV
iCD
C\C
)%
Ck
)t’
)-
-00000000
CC
C—
-—
CC.
--
Vi
Vi
Vi
C—
00-
‘J
CV
it’
J—
CV
i‘J
C-
Vi
t’J
—C
Vi
—V
i-
Vi
—C
-
r-nc/
cli
-.1
1H
>---
E‘
>0
00
00
—
0C
DC
D cli
-
I’.1
—-
—k
)—
——
I’.)
Vi
—
C-‘
C—
t’J
-.1
—0
-—
D—
a00
Vi
..00
CV
iO
bobcboo
oo
<I’
J‘J
Ci
4i.
00
Vi
Vi
t’-)
Vi
—V
ia
Vi\
C—
C)
0)C
Vi
00
0V
iV
i—
100-
—C
Vi
00
—
--
Vi
4-‘
00
CV
iV
i0
0V
iV
i—
-C
00
CV
i-
Vi
—S.
D00
OC
Vi
00
Vi
—t’
JC
Vi
-—
CV
iC
Vi.
—a.i
-—
.)V
i‘-
0a
—a
Vic
L-
c2C
—L
‘-‘
-
CC
CC
C000C
CC
C000C
CC
CC
CC
CC
CC
CC
)-
Vi-
Vi
Vi
CQ
C-‘
CC
0V
i0
.D
‘J
‘-0
C0
00
—V
iV
i
H 0 0) C)
0 Cf)
H C) 0 0) g 0 CO -t 0) C)
C)
-t Cl)
0) -t C)
-t 0 C) I
t)
II
II
II
II
II
II
II
II
II
II
II
II
00
tJts
)t’
Jk
t’.)
t’J
I’J
k)
tJt’
Jc)
tci
—0
t’J
‘Jt’
J0
00
00
00
CV
iV
iV
iV
i—
00
04
—4
- —1000000
Vi
Wt’
J—
0W
t-J
00
CV
i—
t-0-’
at’
—0
000-
(D
H C C) C -t
cl
HH
0’
0)0
)0
)0)0)
-0
)-0
)-C
)-C
)-0
-•
CO
0)0)0)0)
0I
-t1
-00O
OC
)--C
)-
0)0)0)
0)0
)‘0
)0
)0
00
00)0)0)Q
0)
(Tht)
——
——
——
—V
i—
—-I- 0
04
—.
04
OV
i00
Vi
400.
C’
Vi
—.
>C
)V
i0
00
Vi
‘‘- I’,)
Vi
Q‘D
00
Vi
k)
t’J
-‘\0 0 —1
Vi
• •Q’O
0V
ik
-4
-4
ViV
iV
i00
Q.
00- Q—
Vi
.0)
Vi
O—
Q3
k)
C(‘
3(‘
3V
i0
(‘3
-3-3
(‘3
0—
000
00
Vi
00
0V
i0
Vi
Q’
——
——
——
30
Vi
4V
iV
i0
‘(‘
3(‘
300
Vi
00
(‘-3
0V
ia-
I0C
).0)
‘——
I
C I220022229
999999999
—(‘
3V
i—
(‘-3
—(‘-
3—
—V
i.0
)V
i(‘
3V
i1’
)(—
3—
ViV
i0
0’0
0\0
0-0
J0
00
-0 t0)
Guam Power Authority Distribution Analysis 2010—2015
3.6 Loss Factor
Loss factors are required to determine average losses in kWh over a one year period. The
feeder loss factors were derived from an empirical formula. The general form of the Loss
Factor FLS is
average lossFLS —
peak loss
From Buller and Woodrow [Buller, F. H., and C. A. Woodrow: Load Factor-Equivalent Hour
Values Compared, Electr. World, vol. 92, no. 2, July 14, 1928, pp. 59-60] two formulas are
listed to estimate the loss factor for Urban and Rural areas.
FLS (URBAN) = O.3FLD + 0.7FD
FLS (RURAL) = O.1SFLD +0.85FD
An analysis was conducted to determine the appropriate equation for loss factor where
A+B=l.
FLS = AFLD + BFD
Loss factors obtained through simulations of Quantum data over a 24-hour period were
compared against loss factors calculated through the empirical formula to determine the
appropriate values of A and B. As shown in Figure 1, simulations over a 24-hour period
provided loss factor values.
- 13 -
Guam Power Authority Distribution Analysis 2010 — 2015
3000
2500
2000
1500
0-J
1000
D
TIME
Figure 1 — Typical Load Curve
Appendix A provides loss factor data determined from the Quantum simulations as well as
values derived from the empirical formula FLS = AFLD + BFD. FED values were obtained from
the Quantum data and A and B values were selected at 0.05 intervals.
Appendix A also provides the percent differences between the loss factor values from the
simulations and the loss factor calculated from the empirical formulas. Based on the analysis of
this data the values of A and B were determined. The GPA empirical formula for Loss Factor
is
FES =0.15FLD +0.85FD
Appendix B lists the loss factors calculated from this formula.
p’4ILF.O
- 14 -
Guam Power Authority Distribution Analysis 2010 — 2015
3.7 Annual kWh Losses
Annual kWh losses are needed to quantify benefits of recommended CIPs. Annual kWh losses
are calculated as follows:
If
average lossFLS —
max loss
and
FLS =0.15FLD +O.85F
Then
average loss = max loss x F
average loss max loss x (0.15FLD + O.85FD)
annual kWh losses = average loss x 8760 hr
- 15 -
Guam Power Authority Distribution Analysis 2010 — 2015
4.0 CAPITAL IMPROVEMENT PROJECTS
The existing system performance was compared against required standards to recommend
improvement projects. Load transfers, phase balancing, capacitor placement, and re-conductoring
were considered. Combinations of this work were also analyzed. The final capital improvement
plan was developed and prioritized based on immediate operational needs, distribution system
criteria and favorable cost benefit analysis to reduce system losses.
4.1 Cost Benefits
Benefit Cost Analyses were based on an inflation rate of 6.2% (First Hawaiian Bank Economic
Forecast, 2009 Guam — CNMI edition.) Appendices E, F, G, H, I, J, and K list the total kWh
savings per annum and total installation costs for the selected projects using a current energy rate
of $0.098 1/kWh. Appendix M provides installation cost estimates. Improvements can be
justified with a Benefit Cost Ratio greater than 1. The Benefit Cost analysis (BCA) is determined
as follows.
Useftul Life kWh loss savings per annum.Net Present Value of Savings =
(i + Inflation Rate)’
Net Present Value of SavingsBenefit Cost Ratio=
Construction Costs
4.2 Load Transfrrs
4.2.1 Permanent to Address Overloads
P-087, P-33 1, P-242, and P-250 are over 75% loaded. Load transfer, feeder line upgrades, new
feeders and/or substations are options considered to bring these feeders within the GPA loading
standard. Load transfer is the preferred method to address feeder overloads because of minimal
labor and materials required. Load transfers were analyzed between the critical feeders and the
surrounding feeders. Listed in Table 3 are the load transfer values for P-087, P-33 1, and P-250
and the resulting impacts on loading, voltage, unbalance, and losses on these feeders and the
corresponding feeder ties.
-16-
Guam Power Authority Distribution Analysis 2010 — 2015
Feeder Analysis - Load Transfer Changes
Source Amp % Max % Volt MinimumLoad (Metered) MAX Loss
Loading % Unbalance Unbalance Voltage (pu)Feeder Substation kVA (kW) (Synergy)
(Synergy) (Synergy) (Synergy)
Before After Before After Before After Before After Before After Before AfterP-087 Dededo 9,465 6,024 82.0% 51.0% 18.0% 19.7% 3.36% 1.40% 0.916 0.970 448.5 159.0P-046 Harmon 1,553 4,987 15.0% 46.0% 8.6% 12.6% 0.12% 1.94% 1.020 0.960 7.2 130.0
P-331 Yigo 8,829 7,039 83.0% 64.0% 17.6% 19.1% 1.00% 0.68% 0.999 1.008 63.8 42.0P-089 Dededo 4,127 5,871 36.0% 50.0% 26.5% 24.6% 0.88% 1.13% 1.010 0.998 30.7 63.0
P-250 Agana 8,655 7,549 81.0% 69.0% 20.8% 17.4% 1.90% 1.40% 0.952 0.966 331.2 243.0P-294 Pulantat 5,107 6,226 48.0% 57.0% 13.6% 17.2% 1.19% 1.63% 0.980 0.952 130.3 207.0
Table 3 — Load Transfer Changes
Feeder modeling and analysis of load transfers on P-087, P-33 1, and P-250 resulted in 3 switches
installed for a total construction cost of $33,197.61 and a loss savings per annum of $96,267.64.
Assuming a useful life of 5 years, the benefit cost ratio for load transfer is 12.15. Construction
costs and loss savings per annum are listed by feeder in Appendix E.
There is no load transfer scenario available for P-242. P-242 is entirely underground and is tied
to P.403 and P-243. However, these feeders located along San Vitores Road in Tumon are
already planned to accommodate current permitted projects. Consequently, no spare capacity will
be available to relieve overloading on P-242.
4.2.2 Temporary to Address Back-Feeding
Load transfers were also assessed for supporting loads from adjacent feeders under emergency
conditions. Under these circumstances, loading was allowed up to the maximum capacity of the
feeders and voltages were allowed up to 0.95 pu and 1.05 pu in accordance ANd C84. 1-2006 for
emergency conditions. Backfeeding scenarios provided in Appendix N were discussed with
PSCC and T&D to validate existing conditions and feasibility.
All dIP changes to feeders were accounted for in the back-feeding table in Appendix N. Load
transfers were assumed as well as balance improvement, capacitor placement, and re
conductoring. Typically, back-feeding scenarios involved one to one transfer between 2 feeders.
The following list involves multi-feeder coordination for temporary backfeeding.
-17-
Guam Power Authority Distribution Analysis 2010 — 2015
1. P-089 back-feeding requires partial load transfer from P-33 1 to P-332 prior to
transfer to P-332.
2. P-330 back-feeding requires partial load transfer to P-046 prior to transfer to P
332.
3. P-33 1 back-feeding requires partial load transfer to P-332 prior to transfer to P
089.
4. P-271 back-feeding requires partial load transfer to P-046 prior to transfer to P
111.
5. P-ill back-feeding requires partial load transfer to P-243 prior to transfer to P
271.
6. P-242 back-feeding requires partial load transfer to P-240 prior to transfer to P
243.
7. P-245 back-feeding with P-3 10 and P-244 requires line extensions and switch
installations.
8. P-403 back-feeding requires partial load transfers to P-ill and P-240 prior to
transfer to P-243.
9. P-205 back-feeding requires partial load transfer from P-401 to P-203 prior to
transfer to P-40 1.
10. P-2 10 back-feeding requires load transfers and switch installations for peak back-
feeding.
11. P-250 back-feeding requires load transfers and switch installations for peak back-
feeding.
12. P-323 back-feeding requires load transfers and switch installation for peak back-
feeding.
13. P-290, P-292, and P-298 back-feeding requires underground line extensions and
switch installations in existing conduits and switch pads.
14. P-003 back-feeding requires underground line extensions and switch
installations.
4.3 Balance Improvement
Balance improvements were analyzed for all the feeders. Feeder modeling and analysis resulted
in 98 lateral phase changes for a total construction cost of $10,446.80 and a loss savings per
annum of $34,672.01. Assuming a useful life of 5 years, the benefit cost ratio for balance
- 18 -
Guam Power Authority Distribution Analysis 2010 — 2015
improvements is 13.90. The cost per feeder, and number of lateral phase changes per feeder are
listed in Appendix F.
4.4 Capacitor Placement
Capacitors are needed on the system to boost lowest voltage, correct reactive power, and improve
power factor. The useful life of a capacitor bank is 15 years. Installation of 6-450 kVAR
capacitor banks, 6-900 kVAR capacitor banks, and 9-1350 kVAR capacitor banks are
recommended for a total construction cost of $85,408.62 and a kWh loss savings per annum of
$38,348.33. The resulting benefit cost ratio of capacitor placement is 4.30. The cost and number
of capacitor banks per feeder are listed in Appendix G.
4.5 Balance Improvement & Capacitor Placement
Balance improvements and capacitor placements were conducted to correct unbalance, boost
lowest voltage, correct reactive power, and improve power factor. The number of lateral phase
changes recommended in Section 4.3 was applied. Then, capacitor placement was analyzed.
Based on this analysis, 6-45 0 kVAR capacitor banks, 6-900 1CVAR capacitor banks, and 9-1350
kVAR capacitor banks are recommended. The total construction cost is estimated at $95,855.42
with a kWh loss savings per annum of $84,286.20. Assuming a useful life of 15 years, the benefit
cost ratio is 8.43. The cost, number of lateral phase changes, and number of capacitor banks per
feeder are listed in Appendix H.
4.6 Re-conductoring
Re-conductoring work focused on the main line from the substation to the tie switches between
feeders. 336 AAC conductor was modeled for the distribution main lines. An evaluation of 13.8
kV conductor standards is not addressed in this report. Revisions to conductor standards must
consider the effects on current stock of supporting materials and accessories. Loading and back-
feeding capabilities were considered when determining re-conductoring projects. Appendix I lists
the total T&D costs, kWh savings, and total line lengths re-conductored. Assuming a useful life
of 15 years, the BCA for re-conductoring to lower power losses and increase loading capability
gave a Benefit Cost Ratio of 1.48. The total construction cost for the scenario is $558,738.08
with a kWh loss savings per annum of $85,970.93.
-19-
Guam Power Authority Distribution Analysis 2010 — 2015
4.7 Balance Improvement & Re-conductoring
The BCA for balance improvements and re-conductoring combines the recommended
improvements of phase changes and line re-conductoring previously discussed. The benefit cost
ratio for balance improvement and re-conductoring is 2.11. The total construction cost for the
scenario is $569,184.88 with a kWh loss savings per annum of $125,286.73. The cost, number of
lateral phase changes, and wire upgrades are listed in Appendix J.
4.8 Balance Improvement, Re-conductoring, & Capacitor Placement
Balance Improvement, re-conductoring, and capacitor placement is a combination of the three
different methods used to improve losses, voltage, and unbalance. The total construction cost for
the scenario is $654,593.50 with a kWh loss savings per annum of $170,461.35. The cost,
number of lateral phase changes, number of capacitor banks, and line upgrades are listed in
Appendix K. Assuming a useful life of 15 years, the benefit cost ratio is 2.07.
4.9 Project Priorities
Capital Improvement projects listed in Table 4 are prioritized by loading (priority 1), minimum
voltage and unbalance (priority 2), and then reliability (priority 3).
- 20 -
tJtJ
t3L
’JL
i—
C0
0—
*—
—I’
)—
2.
CD C)
t)
I I CD CD CD C CD C) CD CDI—
C)(t
C-a
—-
CD
C) CD CD C)
C) -I
a-.
—C,
)C
.-
CD
.
L)
C.
WL
.J
——
—0
CDC
DC
DC
Djb
CC
CCD
0)
CCD
t’)
l’)
).)
U.
00
0)
Li.
C—
k)
0CD
k)
CC
—C
CD
CD
CD
CI)
CD
0C
DC
DC
DC
DC
DC
D
C/).C
)C
DC
Dc,
1iIT
1.
CC
DT
1T
11i1T
CD
CD
CD
CD
CD
c,
00C
DC
DC
DC
DC
DC
D
i1j1
-°-
Cl)
0CD
CDCD
CDCD
CDC
DC
DC
Dc,
—
CD--
—C
D—
——
*0
CD
ItE
tC
DCD
CD
CD
CD
CCD C
)C
CD
CD
CD
CD
0d
<C
D0
CD
CD
OC
-CD
CD
-CD
CD-a
-i-a
CDCD
92
2o
CD
-.
CD
CD
CD
-aC
DC
-C
DC
DC
DCD
a-C
DC
DC
DC
DC
DC
DC
DC
D-a
gg
ggggggg
gg
2.g
CD-i
C-
CDg
C)CD
CDC
*C
-CD
C)g
gC
-
‘.4
. IH 0 C
0 C U.
C
C C
40
00
0-a
L1
a
p?
wJ
.O
O00
3J
k)
CL
i.
C
C-) I 0 0
0 cIQ
I)
C U.
I’J
C C
00
00
00
C C-’
‘-V C ‘-V t.)
-V C-’
C
‘-;V
;V;V
I’)J D
.
;VV
;V,J
t)t
c4---
‘-V
i-V
-V-V
-VC k
)I
WU
.U.0
0
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00
00000000000000
U.
0)
0W
0)
—00
-t
.D
JU
.U
.00-
0)
—(
3.
—--
-i’
--‘‘
CDU
.4
-k
)0)—
—)
C—
i.0
00
)U
..D
.‘.
03
——
—I’-
.)-
‘J
0)-
C,)
CC
U.
4.
CU
.4.
—00
CU
.—
.D—
\O
Qk)
C0
)0
00
0C
’C
’.C
)\C
C‘.0C
U.00
00
t-JO
0--
00\0
0000C
,)00
—JJk)
CC
0)-0
00
00
CC
CC
U’
-C
000’.O
0C
’.0C
U.
pp
p-’-
04
;:
C—
‘-
——
—I—
)0
0U
..
—4
C-C
D.-‘
-.
C‘.
0CD
oo
00
U.
—‘.
0L
i.00
U.
U.
0)
——
00
‘.0
400
CU
.
CDCD
CDCD
CD HH
(D
S CD
Guam Power Authority Distribution Analysis 2010 — 2015
5.0 LOAD FORECASTING
Information on future load is obtained from numerous sources. Substantial information comes
from the Guam Land Use Commission, discussions with engineering firms and developers, and
plan review records which reflect normal system growth and anticipated growth related to the
military buildup. Based on this growth data, 82.38 MVA of loads were allocated throughout the
system as shown in Table 5. The SPORD division also provided growth data in the form of
annual peaks from 2010 to 2015. Total forecasted growth was estimated at 33 MVA as shown in
Table 5.
Engineering Growth SPOR]) Forecast(MVA) (MVA)*
15.10 923.27 825.87 78.07 610.07 382.38 33
*5QJ Forecastprovided via e-mail on 11-04-2009from SPORD to Engineering
Table 5 — Forecast
Based on an analysis of the impacts of this growth, the distribution system will require
improvements to correct deficiencies and meet system performance standards. 9 feeders will
exceed the 75% loading criteria and 2 feeders will violate the voltage requirements by the year
2015. Listed in Table 6 are loading and voltage issues forecasted up to year 2015. Table 7
provides a list of proposed projects by year.
- 22 -
I I
n1j
Cb)tC
C.
00
CC
00
C k)
D)
(*
-tC
.ru
C-
-t
-
-I)
IC
>—
—I’
J—
-C
-
C -f zH (Th I I
C C C
0 0
H hrj 0 0 -f
0
‘-ct:
II
II
II
II
II
II
IJC
k)k)L
)C
‘-0
00
CC
4C
—0
o•---a—
oo
CC
9.
2-
-—
—I’
)01
—dl
(
ui
N.
00
k)k
)C
Cu
u-‘
‘-‘
C—
CC
Cb
bC
bC
D
CC
CC
0
--t
b<
<r-r-r-’r-’
CC
00000
:3
00 u
k)k)
Jt’-))
CC
——
—f_
A—
e—
——
cit
Ut
.IL’
J—
—II
Guam Power Authority Distribution Analysis 2010 — 2015
6.0 5-YEAR PLANNED DISTRIBUTION CIP LIST
The 5-year planned distribution CIP listing shown in Table 8 lists the FY20 11 through FY20 15
schedule. The list includes all CIP’s from sections 4 and 5. Current issues regarding loading,
voltage, and unbalance are addressed first. Then, the list is sub-prioritized by loss reduction.
Finally, forecasted load increases are scheduled according to the estimated required date as
discussed in section 5.0.
GUAM POWER AUTHORITYDistribution Engineering Capital Improvement Projects (CII’) FY 2011 - FY 2015 X $1,000
CIP Project Name Reason FY10 FY11 FY12 FY13 FY14I P-4(J2 load transter to P-24 1 Loading 11 11‘2 P-087 Line Improvements Loading 13 Ii3 P-250 Line Improvements Loading 82 824 P-331 Lme Improvements Loading 18 18S Commission&bxtendP-112 Loading 200 2,500 3,000 300 6,0006 P-088 load transfer to P-272 Loading 1 1 1 11 P-203 load transfer to P-401 Loading 11 118 P-330 Lme Improvements Voltage 3 39 P-323 Line Improvements Voltage 14 1410 P-322 Line Improvements Reliability 1 ‘I
1 1 Pulantat Feeder Line improvements Reliability 112 Apra Feeder Line Improvements Reliability 3 313 P-260 Feeder Line Improvements Reliability 32 3214 Macheche Feeder Line Improvements Reliability 4 415 Harmon Feeder Line Improvements Reliability 62 62lb Dededo Feeder Line Improvements Reliability 3 31/ Tamuning Feeder Line Improvements Reliability ‘22 2218 Tumon Feeder Line improvements Reliability 46 4619 P-203 Feeder Line Improvements Reliability 38 3820 P-262 Feeder Line improvements Reliability 109 10921 P-261 Feeder Line Improvements Reliability 66 6622 Agana Feeder Line Improvements Reliability 35 3523 Barrigada Feeder Line Improvements Reliability 3 324 Anigua Feeder Line Improvements Reliability 54 5425 Umatac Feeder Line improvements Reliability I26 P-400 Feeder Line Improvements Reliability 1 12/ GAA Feeder Line Improvements Reliability28 P-005 Feeder Line Improvements Reliability29 P-206 Feeder Line Improvements Reliability 34 3430 P-272 Line Improvements Reliability 3/ 37
Install, Commission, & Extend New250 500 500 1 250
31 Feeder at Apra Loading32 P-294 Capacitor bank Installation Reliability 733 P-087 Capacitor bank Installation Reliability 7 134 Commission & Extend P-320 Loading 250 500 500 1,25035 Reconstruct & Commission P-27 Loading 1,000 1,000 800 2,800
Table 8—5-Year Distribution CP list
Priority FY15 Total
Totals: 399 2,94Z 3,Jhi b,U04 hUUU 1,3(H) i,ui
- 24-
Guam Power Authority Distribution Analysis 2010 — 2015
7.0 SYSTEM SUMMARY AND CONCLUSION
The Guam Power Authority Distribution system has approximately 520.76 MVA of connected
load. 152.87 MVA of the connected load is utilized. Distribution losses are 2.044 MW or about
1.3% of the distributed kW, this translates to 49.04 MWh a day or 17.9 GWh per year.
System analysis has revealed distribution performance is adequate and the recommended
improvements are attainable and provide direct benefits to GPA’s quality of service. Further
analysis will be conducted as secondary information including connectivity and loading is
modeled.
1. Meter ID Project — Completion of this task will provide specific geographic
locations for GPA’s 40,000+ meters complete with Service Addresses for ease of
updating through the GPA CIS/Utiligy System. This project will tie in all meters
to the distribution transformer source which will assist with obtaining accurate
SAIFI and CAIDI indices.
2. kWh Allocation — After completion of Engineering’s Meter II) Project, the
distribution model will be updated with customer load information and load
allocation will be performed via kWh allocation. KWh allocation is a more
precise method of allocation that uses the kWh values connected at each
transformer and allocates loads with respect to their contributions. This will
remove any errors with respect to oversized transformers.
3. Transformer Sizing — After completion of the meter ID Project, transformer sizes
will be analyzed to ensure transformers are not oversized with respect to their
loads.
4. Feeder Metering and Load Profiling — The SEL 734 meter will be installed in all
distribution feeders to gather feeder loading data. Completion of this task will
provide accurate historical feeder data for use with the line models.
5. Data Merge (GIS and SynerGEE Model) — This task involves creating a common
database for GIS and SynerGEE for easy maintenance of data files.
6. Transformer and Secondary Modeling — This task aims to model the transformers
and secondary lines of the distribution system for optimization. Completion of
this task will require an upgrade of the line modeling software.
- 25 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.1 Agana Substation
II SUBSTATION: Agana FEEDERS: P-250, P-251, P-252, P-253
Transformer: T-65Capacity: 15/18.7/22.4 MVA OA/FA/FOALoading: 85%
FEEDER P-250
Existing conditionsVoltage Minimum voltage is 0.952 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 8,655 kW with maximum line
loading at 81% of existing line ratingUnbalance Voltage unbalance is 1.90%Losses 331.2kW
Recommended ChangesLoad transferred from P-250 to P-294 to reduce loading from 81% to 69%.Re-phasing will be completed to balance the loads and capacitors will be
• installed to boost lowest voltage, correct power factor, and decrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
FEEDER P-251
Existing conditionsVoltage
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.
Minimum voltage is 1.025 pu with a 1.03 pu distributionbus voltage
Loading The circuit is loaded at 3,874 kW with maximum lineloading at 36% of existing line rating
Unbalance Voltage unbalance is 0.04%Losses 8.7kW
- 26 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-252
Existing conditionsVoltage Minimum voltage is 1.008 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 4,400 kW with maximum line
loading at 41% of existing line ratingUnbalance Voltage unbalance is 0.65%Losses 42.2 kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
FEEDER P-253
Existing conditionsVoltage
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
Minimum voltage is 1.007 pu with a 1.03 Pu distributionbus voltage
Loading The circuit is loaded at 5,554 kW with maximum lineloading at 52% of existing line rating
Unbalance Voltage unbalance is 0.34%Losses 51.4kW
- 27 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.2 Andersen Substation
II SUBSTATION: Andersen FEEDERS: P-067
Transformer:Capacity: 15/18.7/22.4 MVA OA/FAIFOALoading: 110%
FEEDER P-067
Existing conditionsVoltage Minimum voltage is 0.993 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 8,764 kW with maximum line
loading at 82% of existing line ratingUnbalance Voltage unbalance is 0.39%Losses 168kW
Recommended ChangesRecommendations pending documentation.
-28-
Guam Power Authority Distribution Analysis 2010 — 2015
7.3 Anigua Substation
II SUBSTATION: Anigua FEEDERS: P-280, P-281, P-282, P-283
Transformer: T- 100Capacity: 1 8/24/3 0 MVA OA/FA/FOALoading: 50%
FEEDER P-280
Existing conditionsVoltage Minimum voltage is 1.026 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 1,774 kW with maximum line
loading at 17% of existing line ratingUnbalance Voltage unbalance is 0.11%Losses 3.2kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
FEEDER P-28l
Existing conditionsVoltage
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
Minimum voltage is 1.011 Pu with a 1.03 Pu distributionbus voltage
Loading The circuit is loaded at 3,324 kW with maximum lineloading at 31% of existing line rating
Unbalance Voltage unbalance is 0.06%Losses 37.0 kW
-29 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-282
Existing conditionsVoltage Minimum voltage is 1.012 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 5,349 kW with maximum line
loading at 50% of existing line ratingUnbalance Voltage unbalance is 0.05%Losses 37.0 kW
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.
FEEDER P-283
Existing conditionsVoltage Minimum voltage is 1.010 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 3,831 kW with maximum line
loading at 36% of existing line ratingUnbalance Voltage unbalance is 0.55%Losses 39.6 kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
-30-
Guam Power Authority Distribution Analysis 2010 — 2015
7.4 Apra Substation
II SUBSTATION: Apra FEEDERS: P-220, P-221, P-222, P-223
Transformer: T-70Capacity: 10/12.5 MVA OA/FAIFOALoading: 94%
FEEDER P-220
Existing conditionsVoltage Minimum voltage is 1.026 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 703 kW with maximum line
loading at 7% of existing line ratingUnbalance Voltage unbalance is 0.14%Losses 1.1 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
I FEEDER P-221
Existing conditionsVoltage Minimum voltage is 0.998 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 6,103 kW with maximum line
loading at 57% of existing line ratingUnbalance Voltage unbalance is 0.67%Losses 110.2 kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
-31 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-222
Existing conditionsVoltage Minimum voltage is 1 .024pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 1,837 kW with maximum line
loading at 17% of existing line ratingUnbalance Voltage unbalance is 0.0 1%Losses 5.0kW
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.
FEEDER P-223
Existing conditionsVoltage Minimum voltage is 1.0 17 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 5,191 kW with maximum line
loading at 49% of existing line ratingUnbalance Voltage unbalance is 0.45%Losses 44.7 kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
- 32 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.5 Barrigada Substation
II SUBSTATION: Barrigada FEEDERS: P-210, P-212, P-213
Transformer: T-75Capacity: 15/18.7/22.4 MVA OA/FA/FOALoading: 79%
FEEDER P-210
Existing conditionsVoltage Minimum voltage is 1.002 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 6,252 kW with maximum line
loading at 59% of existing line ratingUnbalance Voltage unbalance is 0.14%Losses 87.1 kW
Recommended ChangesNone
FEEDER P-212
Existing conditionsVoltage Minimum voltage is 1.008 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 4,746 kW with maximum line
loading at 45% of existing line ratingUnbalance Voltage unbalance is 0.8 1%Losses 40.6 kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
- 33 -
Guam Power Authority Distribution Analysis 2010— 2015
FEEDER P-2 13
Existing conditionsVoltage
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.
Minimum voltage is 1.016 Pu with a 1.03 Pu distributionbus voltage
Loading The circuit is loaded at 3,804 kW with maximum lineloading at 36% of existing line rating
Unbalance Voltage unbalance is 0.06%Losses 19.5kW
-34-
Guam Power Authority Distribution Analysis 2010 — 2015
7.6 Dededo Substation
II SUBSTATION: Dededo FEEDERS: P-087, P-088, P-089
Transformer: T-55Capacity: 15/18.7/22.4 MVA OA/FA/FOALoading: 110%
FEEDER P-087
Existing conditionsVoltage Minimum voltage is 0.916 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 9,465 kW with maximum line
loading at 82% of existing line ratingUnbalance Voltage unbalance is 3.3 6%Losses 448.5 kW
Recommended ChangesLoad transferred from P-087 to P-046 to reduce loading from 82% to 51%.Re-phasing will be completed to balance the loads and reduce line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
FEEDER P-088
Minimum voltage is 1.007 pu with a 1.03 Pu distributionbus voltage
Loading The circuit is loaded at 7,241 kW with maximum lineloading at 63% of existing line rating
Unbalance Voltage unbalance is 0.5 1%Losses 69.1 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
Existing conditionsVoltage
- 35 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-089
Existing conditionsVoltage Minimum voltage is 1.006 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 4,127 kW with maximum line
loading at 36% of existing line ratingUnbalance Voltage unbalance is 0.88%Losses 30.7 kW
Recommended ChangesRe-phasing will be completed to balance the loads.
-36-
Guam Power Authority Distribution Analysis 2010 — 2015
7.7 GAA Substation
II SUBSTATION: GAA FEEDERS: P-310, P-311, P-312
Transformer: T-105Capacity: 18/24/30 MVA OA/FA!FOALoading: 28%
FEEDER P-310
Existing conditionsVoltage Minimum voltage is 1.022 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 2,756 kW with maximum line
loading at 26% of existing line ratingUnbalance Voltage unbalance is 0.19%Losses 13.4kW
Recommended ChangesRe-phasing will be completed to balance the loads.
FEEDER P-311
Existing conditionsVoltage Minimum voltage is 1.018 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 3,579 kW with maximum line
loading at 34% of existing line ratingUnbalance Voltage unbalance is 0.24%Losses 21.9kW
Recommended ChangesNone
FEEDER P-3 12
Existing conditionsVoltage
Recommended ChangesRe-phasing will be completed to balance the loads.
Minimum voltage is 1.021 pu with a 1.03 pu distributionbus voltage
Loading The circuit is loaded at 2,048 kW with maximum lineloading at 19% of existing line rating
Unbalance Voltage unbalance is 0.20%Losses 6.6 kW
-37-
Guam Power Authority Distribution Analysis 2010 — 2015
7.8 Harmon Substation
I[SUBSTATION: Harmon FEEDERS: P-046, P-ill
Transformer: T-2 1Capacity: 7.5/9.375 MVA OA/FA!FOALoading: 34%
FEEDER P-046
Existing conditionsVoltage Minimum voltage is 1.021 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 1,553 kW with maximum line
loading at 15% of existing line ratingUnbalance Voltage unbalance is 0.12%Losses 7.2 kW
Recommended ChangesRe-conductoring will be completed to improve losses and increase loadingcapability.
FEEDER P-ill
Existing conditionsVoltage Minimum voltage is 1.009 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 6,222 kW with maximum line
loading at 58% of existing line ratingUnbalance Voltage unbalance is 0.06%Losses 70.9 kW
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
- 38 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.9 Macheche Substation
II SUBSTATION: Macheche FEEDERS: P-270, P-271, P-272
Transformer: T-90Capacity: 18/24/30 MVA OA/FA/FOALoading: 54%
FEEDER P-270
Existing conditionsVoltage Minimum voltage is 1.013 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 6,087 kW with maximum line
loading at 57% of existing line ratingUnbalance Voltage unbalance is 0.09%Losses 54.7kW
Recommended ChangesRe-phasing will be completed to balance the loads and reduce line losses.
FEEDER P-271
Existing conditionsVoltage Minimum voltage is 0.997 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 6,530 kW with maximum line
loading at 61% of existing line ratingUnbalance Voltage unbalance is 0.32%Losses 100.6 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
-39-
Guam Power Authority Distribution Analysis 2010—2015
FEEDER P-272
Existing conditionsVoltage
Recommended ChangesRe-conductoring will be completed to improve losses and increase loadingcapability.
Minimum voltage is 1.027 Pu with a 1.03 pu distributionbus voltage
Loading The circuit is loaded at 2,006 kW with maximum lineloading at 19% of existing line rating
Unbalance Voltage unbalance is 0.11%Losses 2.5 kW
- 40-
Guam Power Authority Distribution Analysis 2010 — 2015
7.10 Pagat Substation
II SUBSTATION: Pagat FEEDERS: P-322, P-323
Transformer: T- 115Capacity: 18/24/30 MVA OA/FA/FOALoading: 48%
FEEDER P-322
Existing conditionsVoltage Minimum voltage is 0.992 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 7,503 kW with maximum line
loading at 71% of existing line ratingUnbalance Voltage unbalance is 0.74%Losses 157.7 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
FEEDER P-323
Existing conditionsVoltage Minimum voltage is 0.954 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 7,011 kW with maximum line
loading at 66% of existing line ratingUnbalance Voltage unbalance is 1.23%Losses 162.3 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
-41-
Guam Power Authority Distribution Analysis 2010 — 2015
7.11 Piti Substation
II SUBSTATION: Piti FEEDERS: P-003, P-005, P-007
Transformer: T-7Capacity: 10.5 MVA OA/FA!FOALoading: 44%
FEEDER P-003
Existing conditionsVoltage Minimum voltage is 1.023 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 2,209 kW with maximum line
loading at 21% of existing line ratingUnbalance Voltage unbalance is 0.03%Losses 11.3kW
Recommended ChangesNone
FEEDER P-005
Existing conditionsVoltage Minimum voltage is 1.022 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 2,383 kW with maximum line
loading at 23% of existing line ratingUnbalance Voltage unbalance is 0.42%Losses 11.7kW
Recommended ChangesRe-phasing will be completed to further balance loads.
FEEDER P-007
Existing conditionsVoltage Minimum voltage is 1.026 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 1,402 kW with maximum line
loading at 13% of existing line ratingUnbalance Voltage unbalance is 0.06%Losses 2.4kW
Recommended ChangesNone
-42 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.12 Pulantat Substation
II SUBSTATION: Pulantat FEEDERS: P-290, P-292, P-294, P-298, P-301
Transformer: T-95 & T-96Capacity: 18/24/30 MVA & 30 OAJFA/FOA
MVALoading: 33% & 14%
I FEEDER P-290
Existing conditionsVoltage Minimum voltage is 1.029 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 565 kW with maximum line
loading at 5% of existing line ratingUnbalance Voltage unbalance is 0.02%Losses 0.3 kW
Recommended ChangesNone
j FEEDER P-292
Existing conditionsVoltage Minimum voltage is 1.030 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 83 kW with maximum line loading
at 1% of existing line ratingUnbalance Voltage unbalance is 0.0%Losses 0.0 kW
Recommended ChangesNone
-43 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-294
Existing conditionsVoltage Minimum voltage is 0.977 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 5,107 kW with maximum line
loading at 48% of existing line ratingUnbalance Voltage unbalance is 1.19%Losses 130.3 kW
Recommended ChangesRe-phasing will be completed to balance the loads.
FEEDER P-298
Existing conditionsVoltage Minimum voltage is 1.025 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 2,720 kW with maximum line
loading at 26% of existing line ratingUnbalance Voltage unbalance is 0.01%Losses 8.4kW
Recommended ChangesNone
FEEDER P-301
Existing conditionsVoltage
Recommended ChangesRe-phasing will be completed to further balance the loads.
Minimum voltage is 1.020 Pu with a 1.03 Pu distributionbus voltage
Loading The circuit is loaded at 1,416 kW with maximum lineloading at 13% of existing line rating
Unbalance Voltage unbalance is 0.25%Losses 6.2 kW
- 44-
Guam Power Authority Distribution Analysis 2010 — 2015
7.13 San Vitores Substation
II SUBSTATION: San Vitores FEEDERS: P-400, P-401, P-402, P-403
Transformer: T-122Capacity: 18/24/30 MVA OA!FAJFOALoading: 71%
FEEDER P-400
Existing conditionsVoltage Minimum voltage is 1.021 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 4,609 kW with maximum line
loading at 43% of existing line ratingUnbalance Voltage unbalance is 0%Losses 19.5kW
Recommended ChangesRe-phasing will be completed to balance the loads.
FEEDER P-401
Existing conditionsVoltage Minimum voltage is 1.028 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 1,762 kW with maximum line
loading at 17% of existing line ratingUnbalance Voltage unbalance is 0.03%Losses 1.9kW
Recommended ChangesNone
-45 -
Guam Power Authority Distribution Analysis 2010—2015
FEEDER P-402
Existing conditionsVoltage Minimum voltage is 1.028 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 2,001 kW with maximum line
loading at 19% of existing line ratingUnbalance Voltage unbalance is 0%Losses 3.0kW
Recommended ChangesNone
FEEDER P-403
Existing conditionsVoltage Minimum voltage is 1.008 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 7,393 kW with maximum line
loading at 70% of existing line ratingUnbalance Voltage unbalance is 0.03%Losses 96.5 kW
Recommended ChangesNone
-46 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.14 Talofofo Substation
I SUBSTATION: Talofofo FEEDERS: P-260, P-261, P-262
Transformer: T-80Capacity: 10/12.5 MVA OA/FA!FOALoading: 93%
I FEEDER P-260
Existing conditionsVoltage Minimum voltage is 0.983 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 5,698 kW with maximum line
loading at 54% of existing line ratingUnbalance Voltage unbalance is 0.8 6%Losses 101.6 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will be installed toboost lowest voltage, correct power factor, and decrease line losses.
. Re-conductoring will be completed to improve losses and increase loading capability.
I FEEDER P-261
Existing conditionsVoltage Minimum voltage is 1.002 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 5,650 kW with maximum line
loading at 53% of existing line ratingUnbalance Voltage unbalance is 0.56%Losses 54.9 kW
Recommended ChangesRe-phasing will be conducted to balance the loads.Re-conductoring will be completed to improve losses and increase loadingcapability.
- 47 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-262
Existing conditionsVoltage Minimum voltage is 0.987 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 3,192 kW with maximum line
loading at 30% of existing line ratingUnbalance Voltage unbalance is 0.4 1%Losses 55.0kW
Recommended ChangesRe-phasing will be completed to balance the loads.
Re-conductoring will be completed to improve losses and increase loadingcapability.
-48 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.15 Tamuning Substation
h SUBSTATION: Tamuning FEEDERS:P-201, P-202, P-203, P-204, P-205,
Transformer: T-50 & T-51Capacity: 15/18.7/22.4 MVA & OA/FA/FOA
15/20/28 MVALoading: 54% & 66%
I FEEDER P-201
Existing conditionsVoltage Minimum voltage is 1.018 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 5,250 kW with maximum line
loading at 49% of existing line ratingUnbalance Voltage unbalance is 0.10%Losses 33.4kW
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.
FEEDER P-202
Existing conditionsVoltage
None
Minimum voltage is 1.021 pu with a 1.03 pu distributionbus voltage
Loading The circuit is loaded at 3,897 kW with maximum lineloading at 37% of existing line rating
Unbalance Voltage unbalance is 0.07%Losses 16.7kW
Recommended Changes
- 49 -
Guam Power Authority Distribution Analysis 2010—2015
FEEDER P-203
Existing conditionsVoltage Minimum voltage is 1.010 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 6,979 kW with maximum line
loading at 66% of existing line ratingUnbalance Voltage unbalance is 0.15%Losses 56.6kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
FEEDER P-204
Existing conditionsVoltage Minimum voltage is 1.017 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 7,744 kW with maximum line
loading at 73% of existing line ratingUnbalance Voltage unbalance is 0.27%Losses 48.4 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
FEEDER P-205
Existing conditionsVoltage Minimum voltage is 1.008 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 4,536 kW with maximum line
loading at 43% of existing line ratingUnbalance Voltage unbalance is 0.08%Losses 68.3 kW
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor, anddecrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
-50-
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-206
Existing_conditionsVoltage Minimum voltage is 1.029 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 1,838 kW with maximum line
loading at 17% of existing line ratingUnbalance Voltage unbalance is 0.0 1%Losses 3.2kW
Recommended ChangesRe-conductoring will be completed to improve losses and increase loadingcapability.
- 51 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.16 Tumon Substation
h SUBSTATION: Tumon FEEDERS:P-242, P-243, P-244, fi
Transformer: T-60 & T-61Capacity: 15/18.7/22.4 MVA & OAIFAJFOA
18/24/30 MVALoading: 63% & 70%
FEEDER P-240
Existing conditionsVoltage Minimum voltage is 1.018 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 5,118 kW with maximum line
loading at 48% of existing line ratingUnbalance Voltage unbalance is 0.05%Losses 27.7 kW
Recommended ChangesCapacitors will be installed to boost lowest voltage, correct power factor anddecrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
FEEDER P-241
Existing conditionsVoltage Minimum voltage is 1.023 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 4,094 kW with maximum line
loading at 38% of existing line ratingUnbalance Voltage unbalance is 0.06%Losses 11.9 kW
Recommended ChangesNone
- 52 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-242
Existing conditionsVoltage Minimum voltage is 1.023 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 8,144 kW with maximum line
loading at 77% of existing line ratingUnbalance Voltage unbalance is 0.02%Losses 33.3 kW
Recommended ChangesNone
FEEDER P-243
Existing conditionsVoltage Minimum voltage is 1.027 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 2,031 kW with maximum line
loading at 19% of existing line ratingUnbalance Voltage unbalance is 0%Losses 4.0kW V
Recommended ChangesRe-phasing will be completed to balance the loads. Balance Improvement willlower losses to 47.7 kW at a cost of $319.80 for a KWh saving of $196.85/year.
FEEDER P-244
Existing conditionsVoltage Minimum voltage is 1.027 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 2,662 kW with maximum line
loading at 25% of existing line ratingUnbalance Voltage unbalance is 0.10%Losses 5.0kW
Recommended ChangesRe-conductoring will be completed to improve losses and increase loadingcapability.
- 53 -
Guam Power Authority Distribution Analysis 2010 — 2015
FEEDER P-245
Existing conditionsVoltage Minimum voltage is 1.009 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 5,816 kW with maximum line
loading at 55% of existing line ratingUnbalance Voltage unbalance is 0.17%Losses 64.0 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.Re-conductoring will be completed to improve losses and increase loadingcapability.
FEEDER P-246
Existing conditionsVoltage Minimum voltage is 1.022 pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 4,914 kW with maximum line
loading at 46% of existing line ratingUnbalance Voltage unbalance is 0.13%Losses 17.0 kW
Recommended ChangesNone
- 54 -
Guam Power Authority Distribution Analysis 2010 — 2015
7.17 Umatac Substation
II SUBSTATION: Umatac FEEDERS: P-340, P-341
Transformer: T-120Capacity: 18/24/30 MVA OA/FAJFOALoading: 12%
FEEDER P-340
Existing conditionsVoltage Minimum voltage is 0.99 1 Pu with a 1.03 Pu distribution
bus voltageLoading The circuit is loaded at 2,169 kW with maximum line
loading at 20% of existing line ratingUnbalance Voltage unbalance is 0.78%Losses 33.7kW
Recommended ChangesRe-phasing will be completed to balance the loads.
FEEDER P-341
Existing conditionsVoltage Minimum voltage is 1.011 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 1,352 kW with maximum line
loading at 13% of existing line ratingUnbalance Voltage unbalance is 0.57%Losses 8.4kW
Recommended ChangesRe-phasing will be completed to balance the loads.
-55-
Guam Power Authority Distribution Analysis 2010 — 2015
7.18 Yigo Substation
II SUBSTATION: Yigo FEEDERS: P-330, P-331, P-332
Transformer: T-30Capacity: 18/24/30 MVA OA/FA/FOALoading: 69%
FEEDER P-330
Existing conditionsVoltage Minimum voltage is 0.950 Pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 7,328 kW with maximum line
loading at 69% of existing line ratingUnbalance Voltage unbalance is 1.77%Losses 175.9 kW
Recommended ChangesRe-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
FEEDER P-33 1
Existing conditionsVoltage Minimum voltage is 0.999 pu with a 1.03 pu distribution
bus voltageLoading The circuit is loaded at 8,829 kW with maximum line
loading at 83% of existing line ratingUnbalance Voltage unbalance is 1.0%Losses 63.8kW
Recommended ChangesLoad transferred from P-33 1 to P-089 to reduce loading from 83% to 64%.Re-phasing will be completed to balance the loads and capacitors will beinstalled to boost lowest voltage, correct power factor, and decrease line losses.
- 56 -
-Lc
UOM
surnjppuouRuo)J
MTOJssso1
%8tsiouinqunTOAUTT1JOUTIUBSTXJO%Jt’1,UTp?OJ
OUITUIrLW1XUJMII6E’t’PPoISiflfl3JT3UJuip13O]
flOAsnquoinqu3sipndot1{TMnd6OI!PflOAWflUJIU!J,%4
sUoBTpUo:uisix
E-dIJGI
—orouopnq.qs.z‘(juoipnVAdMOdWVfl9
IV
i00
c’
—c.•
ab00
0c
0\D
c’
ucs
c,
c,
ci
c,
c‘i
Los
sF
acto
rV
alue
sfr
omE
mpi
rica
lF
orm
ula
9p
pp
9p
9p
pb
bb
cu
ccc
-.-
di
4—
\O00-
Cdi-
9999999999
99999p9999
00
00
00
00
00
00
00
-.i
—i
—-a
i
pp99p99p9pp
aa
oc,i
j Li.Li...
g...
jI’
—000d.
--
—-
-—
—-
-—
——
-—
)
9p
9p
99
pp
p9
p9
pp
9p
99
-a
ca
LuL
i.ci.
Lui
ci.
Li.
Li.
-
---
c’
—
C00D
00L
dC
--—
--—
—--
——
—-—
$—
9p
pp
pp
99
9P
pp
p&
-Q
Q0
Li.
Lii
Li.
Lii
Li.
Li.
Li.
Vi
Vi
-(
-1-
--4
--1
-4-
Vi
k)
LQ
00
——
aL
ii-
—d
O00
—a
QL
i.V
iO
00
00
00
00
00
00
00
00000000000004-
.V
iV
ik)
——
00
dO
00
00
—a
OO
Li..
4V
it)
do
00
99
99
99
099
99
99
999
9b
occ
00
00
00
00
00
00
-.i
-a
—-a
-a
—a
—i
-a
-a
-a
-a
dO
00999999999999p999p9
cc.o
00
00
00
00
00
00
000000
00
00
00
00
00
00
00
00
0.
00000’-
0099p99009
9p99999999
00
00
00
00
00
0—
-i—
i-a
—-a
-a
—-J
—i
——
—a
—-a
00-V
i-
0000000009
9900009999
0000
-J---O
Q.O
NC
-a
—0
dOdO
00
—a
c..
Vi
cu-
Vi
I’J
IJ
—0
dO
dO
00
——
0 0 I9o
Po
Po
Po
PoP
oP
o9o9oP
>
PoP
oP
oP
oP
o9
oP
oP
o9
oP
0•
00
cu
Li.
Lu
Li.
LI.
LI.
LI.
Li.
LI.
LI.
Los
sF
acto
rV
alue
sfr
omE
mpi
rica
lF
orm
ula
jT’L
00000000000000000000
400d
O0
03
—
09099909999900999000
-—a
-a
—-a
-—
a—
-i—
-aa
oc
c-.
coV
i_0V
iat—
a—
oc.
99990099
999900990900
ccb
—-i
L—
a—
aLa
La—
a—
a—
ao
oci
00
—-s
oL
i.-
Vi
Vi)
—0
dO00
00
—O
dL
ii-
Vi
Vi
Vi
C—
--—
--.—
---—
—--—
-----—
——
-O
—
99
0p
90
9p9p9900ppp00
-a
ao
-.a
a.
bo
aa
a-.
a-.
VLi
iLi
icu
ci.
ci.
ci.
ci.
Li.
ci
pp999009
p9
99
00
9p
99
00
—a
-a
o-.
a-.
o-.
a-.
c.-
aa-.
ao
aL
i.L
i.L
iiL
iiL
iiL
i.V
.L
I.
------------D
00
00
00
00
00
00
00
00
00
00
LaL
aL
aL
aL
aL
aL
aL
aL
a&
bb
bb
-.
—a
0L
i.L
i.-1
Vi
t—J
—0
dO
dO
00
—J
0.
(I.
4.
Vi
Vi
t—)
Vi
00000009
00
00
00
00
00
0
00
dO
00
3V
i0
0
00
00
00
00
00
00
00
00
00
00 J
.Vt’
J0
0V
id
O00dC
00000000
000000000000
b-.
b-.
b-.
—-a
0.
Vi
4V
il-
J—
—0
dO00
—-a
Vi
4V
it-
3—
t-J
99900000000000990000
0000000000000000
—-a
-a—
-ai
—a
--a-a—
——
-—a
Vi
V.
0000
4-V
i
99999000000000999000
-a-a-ab
Vi
dO
cc
-J
-a0
.ci
.-
Vi
Vi
LJ
—0
dOdQ
cc-J
0.
Li..
0
Guam Power Authority Distribution Analysis 2010 — 2015
APPENDIX A — Loss Factor Empirical Formula Calculation (continued)
A B between Simulatons and Empirical FormulaP-202 P-204 P-243 P-244 P-245 P-246 P-280 P-281 P-310 P-311 P-312
0.05 0.95 1% 3% 1% 4% 0% 2% 9% 6% 2% 2% 8%0.1 0.9 1% 2% 0% 3% 1% 1% 7% 4% 1% 3% 7%015 085 4%- 1% 2% 1% 3°/ 1% S% 2°4 1% 4% 6%0.2 0.8 7% 1% 3% 1% 5% 2% 4% 0% 2% 5% 5%
0.25 0.75 10% 2% 4% 3% 7% 4% 2% 2% 3% 6% 4%0.3 0.7 13% 3% 6% 5% 9% 5% 0% 4% 5% 7% 2%
0.35 0.65 16% 4% 7% 7% 11% 6% 1% 6% 6% 8% 1%0.4 0.6 18% 6% 8% 9% 13% 8% 3% 8% 8% 8% 0%
0.45 0.55 21% 7% 10% 1% 15% 9% 5% 10% 9% 9% 1%0.5 0.5 24% 8% 11% 3% 17% 10% 7% 12?/o 10% 10% 2%
0.55 0.45 27% 9% 12% 5% 18% 12% 8% 15?/o 12% 11% 3%0.6 0.4 30% 1% 14% 17% 20% 13% 10% 17% 13% 12% 4%
0.65 0.35 32% 2% 15% 19% 22% 14% 12% 19% 15% 3% 6%0.7 0.3 35% .1% 16% 21% 24% 16% 13% 21% 16% 14% 7%
0.75 0.25 38% 14% 18% 22% 26% 17% 15% 23% 17% 15% 8%0.8 0.2 41% 16% 19% 24% 28% 19% 17% 25% 19% 16% 9%
0.85 0.15 44% 17% 20% 26% 30% 20% 19% 27% 20% 16% 10%0.9 0.1 46% 18% 22% 28% 32% 21% 20% 29% 21% 17% 11%
A B% Difference between Simulations and Empirical Formula
P-322 P-330 P-331 P-332 P-340 P-341 P.400 P-401 P-402 P-403 AVE.0.05 0.95 1% 4% 4% 71% 6% 49% 23% 23% 3% 5% 4%0.1 0.9 1% 2% 2% 70% 3% 50% 23% 24% 2% 4% 3%O15 ro8 $% 1% 0% 68% 1% 52% 42% 25% 1% 3% 3%0.2 0.8 5% 3% 2% 67% 2% 53% 21% 25% 1% 2% 3%
0.25 0.75 7% 6% 4% 66?/o 4% 54% 21% 26% 0% 1% 4%0.3 0.7 8% 9% 5% 65% 7% 56% 20% 27% 1% 0% 5%
0.35 0.65 10% 11% 7% 64% 9% 57% 19% 27% 2% 1% 6%0.4 0.6 12% 14% 9% 62% 12% 58% 19% 28% 3% 2% 8%
0.45 0.55 14% 16% 11% 61% 14% 60% 18% 28% 4% 4% 9%0.5 0.5 16% 19% 13% 60% 17% 61% 17% 29% 5% 5% 11%
0.55 0.45 18% 21% 15% 59% 19% 62% 16% 30% 6% 6% 13%0.6 0.4 20% 24% 16% 57% 22% 64% 16% 30% 7% 7% 14%
0.65 0.35 22% 27% 18% 56% 24% 65% 15% 31% 8% 8% 16%0.7 0.3 24% 29% 20% 55% 26% 66% 14% 32% 9% 9% 17%
0.75 0.25 26% 32% 22% 54% 29% 68% 14% 32% 9% 10% 19%0.8 0.2 28% 34% 24% 52% 31% 69% 13% 33% 10% 11% 21%
0.85 0.15 30% 37% 25% 51% 34% 70% 12% 34% 11% 12% 22%0.9 0.1 32% 40% 27% 50% 36% 72% 12% 34% 12% 13% 24%
0.95 0.05 34% 42% 29% 49% 39% 73% 11% 35% 13% 14% 25%
-59-
**
*
ti
(C 0*
o
0 frj
0
0 + Oc *
0
0 0
C
II
II
II
II
II
II
II
II
II
II
II
II
II
II
II
II
II
CDIJ
t’JJ
k)
k‘)
t-J
(L
)V
I--1--
t’)
J—
Ct’
J)
t’J
VI
VI
VI0
C0
CD—
—C
C0
00
0—
——
-.C
CC
04
44
4-4-1
.V
IV
IV
I00
00
00
0V
IC
0V
i-VI—
VI
—C
VI
a’.)
—C
0V
i4
VI
—C
I—i
Q—
Ct’
JC
‘000-
cccccccc
IV
IV
i-
—V
i-
aV
I—
VI
IJ0
—‘—‘
Vi
—‘
00
..
vi
.1—
‘—
aV
icc
aV
I00
—‘-
0.1
.C
00
—Q
—.1
—a
—‘C
Vi
—1
VI
00
Vi
‘CV
i—
at)
—Q
VI
CV
IQ
I-’
C00
‘0V
I0
JV
iQ
VI
-1V
i‘0
Vi
—V
iO
CV
i4
-—
aw
o-
‘Ca
CV
i‘-.—‘—V
iC
—00
- 00 Vi—V
I‘J
‘J
00
—0
0‘-
0.
VI
Vi-
-.
Vi
C4.
4‘0
L)
t’J
‘3-
44
‘-0
ViC
C•C
VI
CC
CC
CC
CC
CC
OO
CC
C-V
I:
—1J
VI-00 C C
CC
oC
CC
CC
CC
CC
CC
Co
CC
VI
t-J
k)
0C
0C
Vi
Vi
--
--
-
VIV
iV
I4.V
IV
I—
QV
IV
iVI—
—V
i4.
QV
iC
00
VIJ
00
41.
C-a
Vi
—V
I41
.-a
cc
CV
Ij
—00
41.
t’J
.11.
—V
iC
‘CV
ia
cc
‘C—
C41
.C
VI
00
0‘J
p-.)
Vi
VI
Q-VI00
Vi
C0
41.
41.
VI
CV
IV
i4
—k)
—0
’0
VIV
I.
.—
a.
cM
a’0-a—
Vi’C
.00V
iVi0
00I
oV
io
v- —aco
. .Vi
o-
4V
I4
-0
cc
-Q
J00
00
Vi
I—i
--4
1.
C.11
..-
OC
0‘0
—- -0V
I41
.—
aC
C00I
—a
VI
Ct—
—a--cc
‘o
41.
.cc
--
--
--
-
00000C
000
OC
CC
C000000C
000000
CC
CC
CC
Cg
oo
—a
co—
a—
a.1
1.a
—a
—.a
—a
—a
o—
a—
acc
—a
—a
—a
k)
cc
—a
cc
‘000
—a-
cc
—)
Vi-
—a
—a
cc
—a
41.
—a
VI
C0
00
00
VI
O-0000 C
41.
00
D’-.
VI
Vi
CQ
-—-D
—V
iC
00
CV
I‘)
00
-i * -r1
CDC
00000000
CC
CC
CC
CC
CC
0000C
00
0C
00
00
CC
Vi0-
00
VI
—C
41.
cc
‘o
Q-
Vi
cc
VI
\CV
i—
aC
VI
Vi0
\0a
CI>
-)41.’
0J
Vi-Dcc.11
.—
a‘-
0- * *
CQ
41.
—ao
—a
cc
cc
C—
a—
aV
i—
-a—
ao
cz
o-
—a
-.41..
I’J
-—
10
-—..—.-.—.
—.—a—IN)
Vi-
‘C—..---
-—_--—
VI
IN)
———i-
a—
—i—
a—
——
——
p-a
—p
ai—
ai—
ap
a—
pa
——
—pa
—pa
—pa
—
C—
I—
..
—V
i0
0C
CD
-41
.V
i41
.V
I—
I—
1-
‘0i--
ao
i-a
Ci—
a—
a41
.-
-a5Z
5C
C‘-
0C
C0
CC
CC
CC
CC
0C
CC
CC
CC
CC
CC
CC
CC
0C
CCD
0C
cc’C
CC
CC
CC
CC
’C
C’C
CO
CC
CC
OC
CC
CC
QO
CC
CC
—I
cc
‘c
‘o0
0D
‘0\0
00
0‘0
‘0‘0
00
‘0‘0
‘000
00
00
‘00000
00
00
C.) I
0 +
0 (I)
CM 0 CM 0 ‘S
CO I00 *
II
II
II
II
II
II
II
II
II
II
II
ICD
C‘J)
t’3
CC
CW
I’J
t’J
I’)
t’J
‘JW
L.
t’J
I’J
t)k
)t’
J‘J
CDC
CC
(‘J4
.4.o
oooooQ
ouiu
1L
tIcJI
t’J
—C
-U
W—
‘0
0.1
CI>
.)—
CL
.k
)C
J—
C—
CD I-t
0-t
It
-t-
)t’
.)—
cit
Q’
—a
—tj
cit
c.i
—Q
4cc
00
cc
cit
Wci
t0
0—
aci
t0
0c.
c,I
kt-.
C00—
C—
C—
aw
Lit
1-3
.1.a
Li
.1.
-l’
3Q
cc
cii
Vt
1-3
—a
C-i
Co
4i
C.
00
..
oo
c.Ia-aO
OC
.
Q—
Vt
—4
CC
CC
Cci
tC
C0
CC
0C
C1’
.)cci
00
-
1-3
—00
——
—c
00
cc
—.c
13
cc
cc1-
-)1-
3L
.icc
c00i
00
1-3
1a
c.
,
CC
I-)
Ccc
CL
.i—
-..
LCO
Lit
00
CC
CC
cc
cc
aoo
OO.
Q—
——
‘Q
.—
-‘
\QC
Cci
tci
4c
CD°°bbO
-a
C1-
31-3
13
iC
aC
Ccc
4i
—C C
4*
ci)
-
I.T
j
CC
CC
CC
C0
0C
CC
CC
CC
CC
CC
0C
0C
CC
C0
C co
Q1-
3C
—c
cc
Vt
cc00
—O
-—
cit
C4
C1-
3V
i00
Q—
CV
i00
QC
Q-t *
1.1-
i
0)C
CC
0C
CC
CC
CC
CC
0C
0C
CC
CC
CP
C0
C0
g—
bo
—b
Vtbb
00
1C.
)Q
C—
-1.0
0’
C0
—V
i—
Q00
ci.
cccc
—V
.V
.cc
CV
iC
—at.
.iV
.—
a—
*c,
* *
—a--
Vio
oo
o1
-31
-35
0)C
CC
CC
ccC
C1
-3
C0
1-3C
CC
CC
CC
cQ
ØC
oO
OC
C0C
CC
CccC
CoC
C0C
CC
CC
oC
C
O I
I.tl
II
II
II
II
II
II
II
II
II
II
II
II
II
II
II
II
ICD
‘3t’
JL
’)‘J
c)
L)
--
--
)—0
t’-)
W0
00
CD-
-—
000000
---
0000
44.
4-
4.
-‘G
oG
OG
oC
Wt
0Q
V-
—CLi
.)k
)—0
QU.
I’J
—0—‘
CC
)—0
‘CI
00
—s
tF1G
oG
oG
oG
o
<C
DC
DC
D
OC
DO
OO
OO
--O
-.
.JH
1H
-C
DC
DC
DC
D000
0CI
Z
CDC
CC
GD
GD
DG
Do
CD
m-ii-
o.
CO
OO
OO
--
--
--
-.
-
J-”G
o4iJ
Vi4-”
-V
i0
(J
Vi
Vi
4)Q
0O
IJ.0Iil-)
CDL’
.)V
i‘
4V
iL
)‘0
j0
VI
VI
Go
Go
‘0G
o0
—Q—-
0G
oG
o-
VI
-.‘
.4
C-
VI-
Go0
Q’O
—-o
ob
co
0G
o’O
CO
00
40G
oV
i—0
00
Go
C0
00
00
00
VI
‘0G
oG
oV
i-
00
\00
——
OV
itJ
t’-.)
Go
——
00C
Go
VI
Go
CG
o0
-V
IV
I—
jG
oI’
JO
oo
1V
iG
oV
i‘C
I0-
t-.)
QG
oç
‘04
CO
0.
QD-
—)
—Go.
-‘0
Vi
—0-
‘00
Go)-
-‘J
Go-
VI
O0.
4k
)C
CC
*(I
’)I’J\D
CO
CC
0C
-C
00
C.0-a0
C4
00J0V
i
—‘—
— —O
0C
Vi
Go
0Go
VIC
.V
ICD
t’J
0‘
C0
‘-G
o—-
‘3V
iG
o0
Go
Vi
VI
Go
VI
VI
Go
4t.
JO
‘-0
•t—
)V
IC
‘-0
-‘-
00
VI
O.4
.-O
0i
-‘--O
’-
I’J-G
o0
\0
00
00
00
00
00
CG
o—
VIC
CC
Go
CC
C0
00i-
-)
C00
Go
CT
j-
--
Vi
VI
-‘-
QI—
)-
—L
JC
-—
Vi
Go
k’-.)
—G
oV
iC
—CV
i‘-
0000
—V
I‘-
00
00
4Q
04
Vi
Vi
CG
o00
—ViG
ocji
VI
Go
Ii
0L’JC
CC
s-”G
o‘-
N>J
V)
4C
j-a-
Vi
I4.
00
\0
t-Jc>
t.jV
i0
00
C00O
000C
CC
C0004O
oC
oC
CC
00
--
--
VI
Vi
—L-V
iV
IV
i—
t’J
0i
4G
oI-
J.j-
-—G
oV
Iç
—C— Vi
C‘-
0-
VI
Go
VQ
4-
—C
—VIV
I-
Vi
‘JQ
00
0
00
—C
CC
0G
o—
4000
-00000000000
0V
i—
1V
ij
0‘J
00
VI
0-
00
II
I
C01010
Vi
‘0)
00
10
10
01
—C
OC
CO
OC
IC
IO
CC
Vi
Vi-
Go
Vi1
0I
I1°
dC
Go-
Vi
-I‘-
0I—C
IO
Go
Go
0V
iV
i.V
i1
0‘0
I—
Go
Go
Vi
II‘
0IV
IIV
iV
I—‘-0
I0I—I
IC
Vi
CG
oG
oC
I—
0‘
‘J
Vi
VI
I—i1V
IO
I‘J
O—
Vii
CI
IVi
Ik>
IC—
i..
—N>O
IV
IiC
IC
CI-
CbC
obN
>IIC
IC
CIV
IIIV
iF
_IIb
[
Vi4-.0
I
Vi
CC
‘-0-
-V
i-
VI
-.
\0i’-
>C
I‘>
0->
—a——
—I--‘
>>
Go
—i’-
>t>
I-
i’-
I-C
C0
000
CC
CC
C0
0C
0C
CIC
0C
CC
CCD
CC
CC
0C
0C
CC
CC
C00C
CIC
C0
0C
0C
C‘0
‘0G
o0
‘-0
‘-0
00
‘-0
‘-0
C‘0
Go
‘-0
‘-0
‘-0
Go
001
Go
‘-0
000000
Go
I
1)
00
00
00
00
00
00
N00
O00
00
00
00
00
00
00
00
00
00
00
00
00
0000
0000
00
0Q
00
00000
0
N00
00
NC
00 tp
000
NN
N‘.C
N—
NN
00
00
00
00
C.,
I.c.
Nc0
0000C
N00
00
00-0N
.00000
0N
o0
00
O0
.rN
.
‘cr
I—
N0
00
0c
‘N
I
aj-N
el,
00
00
00
0N
—o
00
00
Cl
00
N
‘fl00
N—
c—.I
00t
N0
Co5
N>
‘-I
000
N‘c
00
.—
N-
N.
rIf)
—If)
‘JIf)
I.
N—
C)
))
I
-°t00000
00
0N
0000
c1
0
<‘
°N
NE
._
000
..O
o0
C)
N00
00
NIfI
00
Cj
-If)
(f),
fl
‘.0-)
N—
‘.0N
—‘
NN
N‘.0
NN
00
00
NIf)
0C
en
——
——
—N
——
——
N—
————----—————
--
—-
ci‘
N00
C0
00
00
O00
00
en
‘.0
*‘t
NN
‘.00
00
00
00
‘.00
N0
00
‘.0If)
ooo
enN
0N
en‘.0
Nen
N00
N0
‘.00
t-N
‘.0en
enC
—0
00
N‘.0
t.
0If)
NN
NIf)
00
If)N
NC
0‘.0
“.00
0N
NN
If)—
—N
enC
00
NN
If).‘0
0‘f)
C—
‘.0C
CC
Ctmf)
If)C
C0
NQ
‘.0en
CC
0C
CC
CN
If)—
CC
0C
‘‘
—C
If)00
NN
I..C
CC
CC
CC
enjC
.
“N
NN
—N
00
00
If)N
NC
enN
—00
NN
—00
enIf)
—0
‘.
;;;---——
—-----
.)
)U
)))c)
‘1))I)’D
’D11)11)
00
--
----
--
--
•0c
c’c
cC
C0
:
.E0eMCj)
C—
enC
—N
enC
—00
—en
If)N
CN
If)If)
If)
00000000j
‘.0Q
CC
CC
N‘.0
NN
NN
NN
Nen
NN
Nen
0C
CN
QI
II
II
II
II
II
II
II
II
I
I.lj
II
II
II
II
II
II
0t)
-4I’
-)k)
I)
CC
CC
C—
CC
--—
aI
000000
u—
—C
—C
CD
00
** H II
0 0 —.
ClD
Cl
00
00
)0
)0
)0
)
-1
E0
00
—.coo
0-i
—-
——
——
)—
—- 0
—.o
o;
0
00000
000000)0)0)0
0)0)0)0)00)0)0)0)00000000
0)000
0r
r0
‘Q
(t—
—--
0‘‘
Cl.
.
bto’—
0C
uk)00
C0
0C
00
J.
00
-P.
U-
0U
.-0
00U
iC
UiU
i—
C0
0-
000
CU
i0
Ui
Q—
4).
—U
iU
iU
i—
‘J—‘ -4Ui
L’.)
00
4U
i0
400
—- -i o r
00
.-I
00
Ui
D00J
CU
iU
iC
Q‘.
000
QC
—C
—t’
JU
iC
Ui
CU
i00
Ui
—4)
.C
’.D
Ui
00
C00
Ui
——
00
Ui
C00
—U
i
Ui
3).
IJ
I—-0
)-0
Ui
4).
—U
it.
)—
—4)
..I
Ui
k)
——.Ui4). Ui—
—0
Ui
4).
00
0i
Ui
ON
00
o0
ON
Ui
‘.0-UiUi ON—a
‘.0
‘.0-ONC ‘.0
Ui
ON
Ui
Ui
‘.0
—000000 Ui‘.
0—
—U
i‘.
0O
NU
iv-.)
00
00
00
00
00
0Q
-0
00
00
00
00
00
00
00
00
00
00
*0_’__-_-.0--
*00
—
‘j0
0C
I-
0
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
OC
——
CC
Ui
C0
OC
Ct-J—
C—
ON
00
Ui-C
CU
iC
C0
0C
a00O
N0
0-0-0
00
00
00
00
00
00
00
..0
00
00
00
00
00
00
00
00
__j
—0
,;i
<:
——
——
——
——
IH
H_
I_
I_
I_
_.IH
_H
IP
IC
iC
IIP
I‘
0I0
ICIC
I’.0
IO
N1001
‘.c10
0C
00
-J
00
00
00
IU
iU
i 1001I—
II‘.1
IIC1
ONON
000
I11-P
.00
ON
-P.
—C
-0000
Ui
(1)
0‘
c,0
,—
‘
II
II
II
II
II
II
II
CDC
CC
CV
ik
)V
iV
iCD
QC
CC
C0
00
t)4
00000000
Vi
Vi
CV
iV
i—
00
CC
Vi
CV
iC
t”.)
**
*V
i
H II
C C rh C
00
.ro
roro
CD0
)C
DC
D)
C— CD
-f-—
—-
oZ
r+r+,-
.‘t-
i
Vi-C
_C
lV
i
CC
(DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
DC
D— O
—————
———Vi
C
‘;—
DC
CD
4-V
iI’.)0
oCD
Vi
Vi
00
CC
C00
Vi
Q’i
Vi
C00
Vi
Vi
Vi
-‘ ViC
Vi
00
Vi
Vi
CC
CD c
Vi-—
)k
—Vi
Vi
Vi
Vi
Vi
—Vi
Vi
Vi
—Vi 4V
i00
00
CV
it’
J. ——00
•C
CV
iV
i00
Vi
Vi-Vi 40
00
0V
iC
Vi
C00
CC
Vi
\QV
i0
-CVi
CV
i4
L’)
—1
Vi
C-Vi
— —1ViV
i‘.
0C
C—
.DI’
-0
00
—V
i‘.
0-‘.04
.4.C 4V
i
—l
4—Vi
——‘ ViV
iV
iV
i—.—t’
.)V
iV
iV
i—Vi 4
.V
i00
00
‘.
-.V
ii—
Vi
QC
Vi
4.
Q—Vi C
QC
—J——
CD00000000000
* *•
00
00
00
00
0
00 — C
DCD
CppC
CC
CC
C-C
CC
—C
CC
CC
CC
CC
C-
000
0--0
00
00
00
00
000
00
00
00
00
00
__
‘0
_-_
-0
0
CD--
-
—‘ —C———
‘-——‘ C——
C-‘CC
C-C—
————— —
C‘.a
—V
i00C
00V
i—
——
k)C
CV
i00
——
—-
--
.<CD
I1!
CP
CV
iacc...-
00
o
CD 00
Guam Power Authority Distribution Analysis 2010 — 2015
APPENDIX E - Load Transfer
Load Transfer
42.063.0
0.640.56
-$3,554.30 $11,065.87
Total $96,267.64 $33,197.61
* kWh savings per annum = (KW loss d(fJ) XLossFactor X 8760hr X $0. 0981
P-331P-089
Yigo
MAX Loss (kW)kWh Savings
Feeder Substation (Synergy) Loss Factor T&D Costper Annum
Before AfterP-087 Dededo 448.5 159.0 0.64 $93,793.55 $11,065.87P-046 Harmon 7.2 130.0 0.62
P-250 Agana 331.2 243.0 0.61 $6,028.38 $11,065.87P-294 Pulantat 130.3 207.0 0.61
Dededo63.830.7
- 66 -
II
II
II
II
II
II
II
II
II
II
II
IC
t)
‘J
k)
k)
4.
)—
CC
CC
—‘-
-C
CC
C-.
C4
44
--
00
00
00
C0
—C
U—
C—
ak)I
Ct’
)—
‘C
000
*
ID
DJ
C))
H•IIIIIII•i•r 00
00
rQ
rQ
CtC
D(D
p9
PP
PP
PP
PP
9C
CC
cP
PP
PP
CP
9P
00P
PP
Pp
—aa
--ao
t-a
a-C
Lt
0o
—ao
CC
C—a
00
0U
iQ
’o-
va
g.—
Q0-P
.0
c,z
3:
4—
——
k)
I—’
—Q
Ui
Ui
UI
cj
00
-0
DC
.-P
’-
—t-
)U
IC
01
UI
CU
IC
CC
CU
I—a
-‘
—C
Cç0
C—
--
--
-----------
C
—U
I00
UI
UI
—U
IC
Q—
UI
——
0U
I—
IS)
S)
CU
I—
CC
00—
.00—
C0U
I.
UIO
0O
--3-
rjU
IU
I—
UI
UI
UI
—LI
-I
CU
IC
CC
CC
CU
I0
-U
IC
CC
00
*4ee
*e
*e
e(
*
-‘
UI
--IS
);_
_IS
)I
.U
UI.
I—’
——
-C
00
00
00
CU
I4
\Q4.
IS)
CI
II
II
II
II
III
PP
1\
IS)
.j
—Q
UI
CC
00
—)
-100
00
UI
aU
I—a
IS)
—a—a
—aU
IU
IU
I—a
—a—
*
,,,,
,,,,,,,,,,,
,f,,
))
.-
—U
IIS
)IS
)-.
I0
UI
UI
UI
—I’
-)—
CC
C—
——
CC
UI
-U
IU
Io
IP
II
UI0
IIP1
I‘-
Ce
ii
II
IP
’I
.lC
00
IS)
I—)
C0
C00
CC
IC
CC
CC
CC
CC
CC
CC
C!.
o
I
0 0
IS)
—
C-
—D
—4
‘—a‘
—U
IC
00
1’-)
C0
DU
IU
IU
ItS
)00
0C
C-a
-au
-C
IS
C’0oIS
UI
CC
UI
00
00
—a
—0
0C
00
UI
0U
I00
UI
--
UI
UI
UI
---i
—a—a
‘-C
II
II
II
II
II
II
II
CDD
’)t’
3C
CC
k)
t’—)
-ai-
ai-
aCD
t-J
1-3C
CC
CD
00
00
00
00
JI
Ui
Ui
UI
C—
cMc.
)0
0C
1-3
CW
1--3
C
*
ITO CD CD CD
ON
00
I11
-iii
ih;P
iiI1
Hhif
lI
CO
CC
CC
CC
CC
CC
CC
CC
CC
CC
OC
CC
OC
CC
-.P
.00
—U
I.
UI
ON
ON
—.
.1.
1-3
00
ON
UI
.l-1
ON
UI
4U
IO
NO
NO
NO
Ng
UI
ON
C-
3O
NC
ON
——
ON
00
UI
OO
-U
IU
IQ
CcM
C—
av
—a
I
- r- 1-
i-a
cMU
IU
I1-
3-
1-3
1-3
1-3
UI
00
—U
I.
—U
IU
I—
o
c,
—1--
a—
-—
UI
--
--
t-I
C—
—‘
—U
Ic.
a
CC
.0
04
D.
CU
Io
cci—
ai-a
ONC
C—
UI
00
I
-i
——
UI
cM
k4
—k)001
i-ab
ta
C1-
3—
UI
.U
I4
1--)
C—
-U
I4.
oo
UI
i—a
z.—
II
II9°P
—--P
90°P
9°-
UI
CU
Ii-
ai-
aO
1-3
UI
UI
—a
cc
UI
00
00
ccO
Ncc
UI
—3
UI
UI
—3
1-3
I—’
I—U
IU
I—
k)
00
-1-
3* T
1—3
2.
1--a
UI
UI
UI
i-a
—-a
k)
1-3
1--)
UI00
UI
4—
UI
UI
—3
I——
——
1-
—I—
-U
IU
IC
I—1-
)C
——
.IU
I‘-
Ccc
CI
UI
ON
UI
UI
UI
UI
1--a
ON
‘-0
ON
ON
cc
ccO
N•1—
a0
00
00
01-
3i--
aC
00
ON
004
ON
00
00
1-3
‘1C
CC
CC
CC
CC
CC
CC
CC
CC
Co
IC cM ON --a ON i-
ai-
a
i--a
CD CD II-’
i--a
—‘-
CC
N’J
C—
300
--a
—a-
-a—
-
r-i
-‘
0-
01-
3U
I—
ON
—C
UI
UI
00
CU
IC
ON
ON
1-3
C—
UI
—3
UI
00
ON
—)
—100.
00
DC
—1
CC
1-3
UI
‘-0
CI—
)U
I’-O
ON
4-4
—100
—
UI
W1-
3\Q
——
—c
—3
0000
-1-
3
I-) 0 1-3
II
II
II
iI
II
II
ICD
t’J
L’3
t’J
I’)
--1
-l-
CC
CCD
-‘C
CC
C—CC
CC
-000000
CN
JC
‘)
—.CC
—C
\Q00-
CD -* I El
ON
O 0 4.4
I.O
OC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CQ
—O
-0
0t..
).4
.V
QC
(J-
QU
.—
10
U.
U.
CQ
a-
00
QO
U.
QU
.)
U.
g0
)—
C.
00
0Q
U.C
000U
.U
.—
000
.1-C
C-1
0 -4 fl::
——
——
——
——
——
0C
h
40
-.-
C0
—(_
)U
.C
CC
CC
CC
CC
CC
CC
CC
CCD
C)
--
-
—400
QJi—
U.
0D
C0
00
00
PP
’—
U.0
.—
CD
I’-)
C0
CD
CC
U.
—C
C—
CD
0—
CU
.U
.U
.D
U.U
.O
,>
9°90
P•‘C
CI
.o
—..
CO
CD
CC
.C CU
.C
CC
—CD
10
CD
-4-
—-‘
—c,‘b
—‘c
‘oo
—-1
——
C-
—U
.U
.U
.I
II
II
II
II
II
II
II
II
I°
II
II
I-J
.4-
—a
k)
t)—
t’)
ak)
D—
.JD
00
U.
CU
.4
k)
—*
**
F,
9*
*69
Hk
)0
0‘J
1’J
id0
idid
idid
idid
id‘:
4id
i4
DD
.4
D4
4I
II
II
II
II
II
II
II
II
I—a
—
II
04
-IL
did
..
-tj
4—
—D
idid
—1
—.
—a
id—
-
69696969696969696969696969696969696969696969
69
68
69
61
6999
3D
i’)‘0
0ld$
‘o0-
‘bo
U.
C-
—a
U.
DU
.C
D.i
-U
.a
—II
U.
DU
.C
4r-
’-
C—
k)
00
CU
.U
.00
U.
C‘-
‘—
‘—
—‘—
—
II
II
II
II
H
i__i
II
II
II
II
II
II
II
II
CD‘J
CC
Ck
).)
L’J
)L
’J‘J
CDtJ
I’.)
tJC
CC
Oa.’
IJ0
00
00
00
0c
Vi
L..
—C
Vi
00
Cl
—C
tJ—
0
* CD -i IC
0 S 0 C
Hiii
pO
CC
p0
00
00
00
00
00
00
0C
CC
000C
CC
—.
00
—V
i-
VI
a.’
a.’-
t’.)
00
.‘
Vi.
a.’V
i-
Vi
a.’a.’
a.’a.’
gV
ia.
’C
-10.
’C
a.’
—‘l
—0.
’00
Vi
CC
—.
Vi
Vi
OC
VI
CV
IV
i—
C (-
——
——
——
—I
0 I-i.
’
.-.
-‘
I-
-.
44
CID
Vi
Vi
CV
iV
iV
iV
iC
CC
CC
CC
CC
CD‘
--
-
CD -I
:-
-C.
VI
VI
C0
-l
Vi
00
t..)
C00
tJ—
.C
C.’
—0.
’C
4.
00
CC
VI.
1c
c00
—0
0C
Vi
——
a—
‘a.
’
-
-—
IJI’
30.
’0.
’3
‘i’j
‘.0’C
k)
‘iJis.)
40
00
0C
.0
44.
II
II
II
II
II
II
II
P’P.’
II
I..
I.)
44
44
I’-J
.4
44
-4.
-
‘IC CD CD CD
00
00
00 (‘I
00
00
00I
II
—I
II
00000000000000
00000000000000000000
00
00
00
00
00
00
00
0.’
0.’
II
:.cV
iC _
_
0000
k)
Vi
$.
VI
CV
iV
i00
CC
Vi
00
‘J004
—0.
’V
I%
_%
__
VI
a.’
0.’
00
VI
C
‘rj
II
II
II
II
II
II
II
II
II
II
II
II
II
II
II
ICD
‘J3
t’t’
JL
Jc
3.i
..
-1.
I’J
LL’
Jk
)t’
JI’
J—Ct’
Jk)
t’J
00
0CD
C0
0000
I-’
——0000
..
.4
44
-—
DW
I000000
C(J
.g— L
3—0
—0O1J.
—‘0—at
—0C
\Q00
*
II
00000
000000000C
CC
CC
0C
0C
CC
00
CC
C0
0g
oo -,
4tJ
—-—
— —a
fli:
———
———
———
—I
0c,
II)
3—
—0
‘04.
ci
00
00
00
00
00
00
00
CD
40
0)-
-
\Q
C0
00
0P
.
oC
OçjC0
00
.C
---_2
0—
00
C4
‘J
—L’
J— 0
—— v—t’
Jo
u—c.
oa
-aoa.
-W
e..
CD.f
U— t
ui
çj
0C
0a
0—00
wa
C0
000
I f(
(9
rk
)k
)‘)1
Jt)
——4
—L0
0C
—0—0
CC
00
-‘
00
(Th.
-C
0D
-.D
C0
tI
bo
)Q
’Q
00
00
04
C—
00
--.
0C
0k
)—
—a
o-
Ct-
J—
C—
C
I
I CD CD C) C C)
CD CD
-‘
00
00
0I
-LM
C0co
** --— ) 0
0— --
aIpIpI-
III
c.
-o
C)
00
1%
1—
%_
—
IJI90
—00
4—
00
t’J
C
C
Tj
II
II
II
II
II
iI
II
II
ICD
Ct’
Jt’
Jk)
CC
I’J
kk
)V
iV
iV
ik)
JCD
Qt’
Jt’
JC
CC
k)
t’J
-1.
00
00
00
00
Vi
Vi
Vi
Vi
—C
IV
iV
i0
0C
—C
—c
—c
CD -I
*
L’J
C 00
00 00
00
00 00
00
-i
CD
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
CC
O-
—a
.f0
0I-’
Vi
4V
iC
-1.
-.
00
CV
i-
..
QV
i4
Vi
Qa
g0
Vi
00
-10
CQ
Vi
—a
00
Vi0
0V
iV
i\Q
CV
iC
—V
iV
i—
0 -,
zt)
Vi
Vi
Vi
k)
L’)
Vi
00
—‘
Vi
—V
iV
iCD
Q
c,—
(T
h—
kb
a—
——
——
—a
.‘
——
4-
4cm
Vi
Vi
Vi
Vi
CV
iV
iV
iV
iC
CC
CC
CC
CC
CD
4‘‘
Vi
Vi
——
—V
iV
iV
iV
iV
i4
CV
iC
Vic
o-
aC
C
---
C0
0.
0V
iC
Vi
00s
;-.
CC
C—
00
00
C.
(D
00
00
000000
00
00
00
00
00
00
00
00
00
00
00000000000000
\Q0
0V
i—
——
——
3>
.1V
i)
-—
t-JV
iC
C00
I-J
—‘
-V
i.I
Vi.
Vi
CC
i—s
Vi
I>.).
—V
iC
—a
—a—
C’
Q0
——a
Vi
00
00
t’J
-J—a
Ca
ooC
00
Vi
CV
i—
‘
-V
i’C
)t’
J\Q
ViC
Vi0V
i0
00V
iQ
0’C
Vi0
0—
.Vi
Vi
—1
0V
iC
ViV
iV
i—
)—
--—
C
000000000000000000000000000000
0000000
00
00
00
00
00
00
00
0
t’.)
Vi
Vi
L’-
C)
t-t’
.)V
iV
iV
it’
)--
Vi
—V
i4
1s3
—V
i-)
4-i--.
-.
—C
—0
C0
1C
Vi
—1
0D
0V
iQ
Vi
Vi0
DQ
oV
ia
—V
itJ4
00
00
00
t-L
’JC
Q0
0)0
OQ
‘-4
C—
aC
CC
CC
CC
4-
t-)
CC
C—
aC
—a
C-
—a
— 0 .4 O .4 0 S .4 0
0
I
00000000000000000000000000
—.
LJ
—C
000
0I-0
CC
00
CV
iV
i4
p’p
’p
>I
I0IJ—
00
QC
000V
iV
i—
a‘0
-V
it’
J0
CV
it’
J.—
%_
_—
‘—
‘-__
—0
00
tJC
-0
00
0C
CQ
4-k)
Vi—
).—
%_
_—
00
00
Vi
——
——
—C
o-V
iV
iV
i4
k)-C
Vi0
0V
i—---i0
0V
ik)
-00
0Q
Vi
—%
__
—-_
H
II
II
II
II
II
II
II
II
II
II
ICD
L’J
tJL’
JW
t’J
)C
I’)
t’J
t’)
WC
CC
CDI-
CC
CC
-‘C
44
-4.
W000000
CD-.
CC
UD-
—0
C(J
0a-
t’J
—CI’-) —C
\D00
--.aCD ,
* ( CD CD CD I
C .4 I
Ir-.iiir
‘0Q
000
PP
PP
PP
PP
PP
PP
PP
PP
PP
PP
PP
PP
PP
PP
PP
PC
CP
P-1
--.aa
-.-
-.
c-o
-o
a.
a--.
a-u
uo
ca
ooo-
0U
Do
-.
oo’
UD
Qg
W-
C.4
)00
00
UD
C0
0U
.0
-C
Ui
C0
Ck
)-l
.D
Ui
C00-
—ao -io
C)
—(— —
Ui
CD
‘—ta
iS-.
D<
100
0—I CD
C0
0-.-
0-
C-p
.-•C
)I
•°°°b
0
0U
iU
i0
PC
C‘ç
Cb-1
--
----
01
’I
It-
.)-1
—D
’3C
(Ji.
CD.
..
..
.k)C
004
C0
CC
C
1ç
II
II
II
II
II
I9°
II
IS’
-9°
II
00
‘J
OC
Li)
O‘J
--.-)
C*
LQC
C—Li
II—
iC
CL
iC
CM
HL
i-
—I-’U
iL
iI
-U
i4
00
L)
Li
Ci
-.-
.I-
—‘‘b
-1
-.--.i-’èo
t’-.)
‘.0
4‘.
0I
II
II
II
II
II
II
II
II
II
II-
.)C
t’)
0Q
‘-0
‘.0
00
I’.)
‘.0
‘.0
00
00
400
Ct’
JC
0C
iC
’,
I
D C) C C)
.4 C
**
——
.-
j’3
00
0C
UD
‘.0-i
Ui
‘.0
-.—
Ip-i
.M
MV
iV
iI’
Jt’-
.)V
i
II
II
II
I
Vi
I’J p-i
‘.01
-d
H 0 Ht’-
.)C
’,C 0-
i
II
II
II
II
II
II
II
II
II
CD‘J
CC
Ct’
JCD
CC
C0
‘DC
IJ
40
00
00
00
0cM
UI
Vi
Vi
C—
aV
ic
—.
00
4C
oCD -I
* e Co 0 -i 0
—1
C .4 C C
0 — (‘I
.4 00
“0
“C 00
00
00
—-I
-—I
0 .4 (JI
iIII
IHP
Hin
i—
-a—
—-a
-i00
i-
Vi.
Vi
——a
-i-.
00
QV
i.(
-1O
Vi
4V
ig
0V
i0
C--.
.Ia
Ca
—c.
—o
00
Vi
CD
—-a
Vi
Vi
‘.0
0l.
C—
aV
iV
i—
-a—
—C
)—
.o
—O
_t’
J00
Vi
—-
—CD
C
C0’0
—-a
w
UiV
iV
iV
i
C’.C
bC
-1
--
-C
4’-
Vi”
C
—N
I
CC
CC
C
(D
L)
Vi
-)
‘‘
-‘:—
--a’Ji
—.
3‘.
0—
I’JC
CC
II
II
II
!“I
II
—‘C
’.C
--
°‘
CV
iOO
.)
I C0’-
4‘-)
000V
i00
‘.0
-—
—a
C)4
‘.0
‘.0
‘.0
II
II
II
II
C0
Ci
CV
iV
i0000
.C
‘C
çD C) 0 C)
.4 0 tI.
II
II
II
I
—-
-—
CQ
—’
4t-
JcJIJ
L’3
00
bo’—
‘.0
Vi
)C
00
—-
‘.0
‘.0
o3
aII)Ilp
.I
ViV
iQC
—a00V
itJ
C4
C—
‘—
——
%-d
S..
—
H 0 H
)J
LJ
JJ
JI’-
.)i’
.)V
iV
i-
44
‘J
t’J
)k
)k
)-‘
0L
’J‘J
Vi
Vi
Vi
0—
——
00
00
00
——
——
0000
-..
4.
.4-
4.-
,-‘-
Vi
Vi
Vi
000000
Vi
L’-.)
0V
i4
Vi
IJ-‘Vi‘
3-‘0
ViJ
00
Vi
3V
i0
QI’.
.)—CJ
0C
00
T1
CD CD 0-
*
CD 0 0 I
NM 0 0 S.
00000000
0000
o00oP
oocco00oopcpo0ocpppp
oo
oo
po
0—
a—
aa
k)-
Via
0V
iC
-C
Vi
QV
iV
i0
CQ
-0
°o
aV
ia
og
0V
ik
)—C 4
00
OO
Vi0
00
Vi0
Vi
—.0
Vi
Vi
0C
C0
k)
.1C
Vi-
C00-
—co-
o -O
4.
)— —
Vi
— —a
Vi
Vi
Vi
0V
Vi
—‘
Vi
— .—V
iV
i0
-V
iL
JtJ
—\D
00
‘-0
‘-0
Vi
—‘-
0-
CD0
00
‘-0-
-0
-I
-
•0•V
iV
i—
.0.’
00
04V
i—
Vi
ViV
i0
0°P
P-
Po
0V
iQ
Vi
0V
i•
-C
0‘-
0-
Vi
Vi
00
00
Vi
Vi.
-o
Ccc
0
C
0—
Vi0
0I—
Vi
‘-
0Vi
——V
i0
Vi0
0Ji.
CDV
iV
i— 0
Vi0
—a
-i
0I’
JV
iC
‘-
00
00
0V
i0
00
0-
Q0
00
00
—V
i;—
Q‘J
t-J
—.
‘-0
Vi
Vi‘-
t’3
Vi
Vi
Vi4
‘—
‘‘—
E—Vi—
t’J
000
00
— —C
Vi
0V
i00
Vi
.\Q
--
Vi
QV
i—
.-
C—00
-Q
4—
.io
—
cc0
0-J
L-.)
Q-
Vi
00
—a
C<
IV
i00
—a
400
00
-1.
*0
\QC
Vi
0t-
J—
s—
1V
iV
i—— ‘
-00
—)
Vi
Vi
—a-
—c
Vi
—Vi
-—
Vi
Vi
Vi
4V
i4
00
Vi
Vi
0—
k)
‘-)
40k)-
——V
i‘-
0--
a4
Ci—
Q’V
iVi4
J.
0—Vi
CC
—04
4Q
Q0
00
0V
i—Vi C
(Th
I009I
II
II
I00L
-J’-00
00
,a’-0’-0V
i—
0.
)00
00
C0
‘-0
‘-0
Ct’
J- Q
C0
00
0C
00
00
04
C0
0000
t-)
(‘J00
00
00
00
Q
0
0 0 0 0 C)
C 0 C
Vi
— t’-J
c 00
ViV
i0
0IJ
Ip
Vi
ViV
iC
—0
DV
i
00
ViV
i-J
Vi
0’0
‘-)
——a—00
0V
iV
iV
ik)
00
-I!‘
-•-.V
II
‘-0
- I—aV
iI-
\0V
i—
a00000
Vi
--0
—ViV
i—
D—
—‘—
,—
%_
‘_,
‘—
%__
C
Irj
II
II
II
II
II
II
Ii
II
II
iI
CDt’
JC
CC
Vi
3t’
Jt’
JL’
3I’
J)
Vi
Vi
tJCD
t’3
CC
00
\QI’
J4
00
00
00
00
Vi
Vi
Vi
)V
iV
i—
00
.4.
t’J
k)
—0
Vi
CV
iJ
—C
I’J
—0
* ( CD IC 00
I U’
00
U’
C’
00
00
00
00
00
U’
hiii
(II
CC
CC
0C
CC
CC
C0
CC
CC
CC
C0
CC
CC
C0
CC
Vi
CC
--
OC
C—Vi —
Q00
Vi
‘-D‘-
0—a
Vi
Vi
‘-0
CV
iC
—1
Vi
Vi
I-i
k)
Vi
Vi
Vi
—at’
Jt’
3V
i0
0—Vi 4
—V
iV
i-D
CD0
-J
QI-’0
‘.)
00
Vi
-1-k
)‘-
00
Vi
C0’
i;
o•
—-V
i-.
CV
i-
0C
.kt—
.
t-
0
C.
00.
‘-04
.C
Vi
-0
C0
—Vi00
*,
,,,
9,,
—
—_
p-
-V
i.
—‘ —1—‘CC
00
4t’
0.
CV
iV
i‘-
0-J
—V
i4
Vi.
—ao
I—’
—i—
’V
i-
00
Vi
C—
a-0
0-
I—’
—a—
.it-
JI—
’i—
—C
000
—aC
0—
ViC
IL
i)k
)ts)
C0000V
i—
0L
i0
0‘-
0O
O—
a-’
•‘-0
Vi
-V
iV
it—
a00
Vi
—s
— —‘Vi
Vi
— 0(—
)k
a—a
0
—I—
]
C0-
4V
i00V
i00
4C
00
I’)
Vi
Vi
Vi
.3- 00
00
Vi
00
Vi4
\0— LiV
ik)
-i—i— —
4.
0V
i0
Vi
Vi
C-
‘-0
0——
(Th
Vi
00
0V
i0
Ca
t)\0
00
Q0
‘-0
00
000
00
i-a
00
00
00
C0
00
00
4C
Q—
00
—aC
C0
CC
C0
0C
C0
CC
0C
.C
QC
0
CD CD CD I
-I-_ -Vi 4
00
C00
Vi
——0
0)
=-0
Vi-.00
—-a
0V
I00
0C
‘-0
0Q
t—.)0-
—.
Vi
Vi
Vi
Vi
1’J
0—‘
-V
iV
iC
00
00
CC
Vi
-—C
-0
0V
i0
C0
00
0V
iQ
44
C4
00
00
—a
Vi
Vi
k)
C—
Vi-
Vi—
.i-’
00
00
4.—
a0
—,
-,
‘—
‘—
S.—
‘-
5_
_5
__
5__
—
H C H
H0H
‘.or
0•
00
00
ClC
Cr
‘-L
‘—
‘—-
‘,0.
N ‘-4fl
00
N‘fl
CC
00
Cl
C0
—0
If)
1(r-:odoc
I-
d‘od
-c
c‘t
‘.0‘.0
N0
NC
lC
l-
N0 L4’
00
CC
l:€
‘-
0CCN
0,-
4‘.
NC
l-
00
l—
2:---
‘-
“—
j
00
‘:1)Eci)C-)
CC.)
c-)td
.CI.
C.)
CI 01.100C
?
0EC?
z
.‘-
0-0•“:
L0
‘.0N
0N
Cl
00
00
00
00
0C
l-0
0000
0N
—00000
‘.0‘.0
Cl
0CC
‘.0C
00
‘.0‘.0
Cl
Cl
‘.0C
loac‘ir
II‘c
‘‘‘.o
‘‘.
Q0
00
-’
00
00
Cr
O‘.0
0-‘
00
CN
‘-
0C
l0
r—
oo
——
1C
lC
IC
l‘.0
N‘.0
‘i
I1)
00
‘.0N
“t
Cl
cC
C-
Cl
-
H4
66
E44
Cj
—N
Q00
tr
Cl
0C
C0
00
NN
Cl
C‘.0
1C0
C‘.0
0..
‘tt
000
000
‘t
N0
Ir
‘.0—
N—
Cl
Cl
00
CC
l.
II
I<5
I’.
C00
IfC0
Q—
QN
‘.000
00
0—
N—
——
-c)
Cl—
4rC
’j
Ir
—‘.0
CIC
I0’.0
00
Cl
-0
Cl
‘.0C
lr
—0
‘.0—
—.
——
Cl
—V.
04
40
r)V00
000
•N
IflIrC
——
N00,
‘.0C’C
‘C
l‘.0
00
N0
N00
N‘.0
‘.0—
fC
00
Cl
‘.0C
l—
r”<C
l-
—0
—C
lc’<
—I-
Ic’
Cl
00
—0
)
.00N
—N
C‘.0
’.0
00
00
N0o
.—
‘.
‘.0—‘-
It—
NC
l-
‘.0—
—C
—C
lcfl
-l’r
‘.00
0—
N0
•000
‘I
C)‘<I-
0N
00
0V
-—O
N‘.0—
C00
N00
Cl
‘.00000
NC
IC
lr—
0If
C—
———
rC
)—04(4)
00
00
00
0C
.•
If
00
00
0tf
UC
l)—
0O
——
C.
0—
——
——
——
*—
—ç)
C-4
-0
)C
If)If)
4)
‘.0—
—C
lC
l—
——
CI
UI0
-to
oc
Nf)C
l0
Cl0
’.0
nO
N0
00
Q00-0’--4C
ln
0
00
0
I
NN
00
0)
000C.
‘.0
0Q(4-
00
0)0
-0
Cl
‘.0-‘
Cl
II)
‘.00
‘C
ln
0-
Cl
cn0000
cnC
)N
NN
—‘1-
‘(t•0000—
000
000
cnC
)C
lC
lC
l0—
Cl
Cl
Cl
Cl
Clt
Cl
Cl
Cl
Cl
II
II
II
II
II
II
II
II
It
II
II
I
1-tj
II
II
II
II
II
II
II
II
II
II
Ii
Ii
CDC
bk
t’J
0C
CV
ik
)L’
3V
iV
iV
iV
i‘J
t’J
‘Jk)J
CDQ
I’J
‘)J
0C
C0
‘.0
‘.0
‘.0
‘.0
00,
CI’J.
40
00
00
00
0V
iV
iV
iV
i—
.k)
I-
CV
iV
i•
00-
CL-
)0
Vi
‘J—
CV
it’
J0
Vi
C
* ( I00
H C (M GO
Ui
—I
Vi
Ui
C’.
Ui
Ui
Vi
Ui
GO
I-
Vi
I-.
Ui
00
0000C
CC
0000C
C0000C
000C
CC
OC
CC
—.4
00
—V
i.
Vi
0’.
0’.
-.I
00
0’.
Vi.
-0’
.V
i.1
Vi
0’.
0’.
0’.
0’.
gV
i0’.
C-
0’.
C0’
.—
Vi
i—a
0’.
00
Vi
‘.0
‘.0
Vi
Vi
‘.0
CV
iC
-aV
iV
i—
JV
iV
iV
i.)
k)
I’3
k)
Vi
00
—V
i.I
—V
iV
iG
CD0
()*:
—tJ
——
——
‘-‘
—o
r.,
4-‘
—‘.
0‘
-.
(I)
flV
i‘.
Vi
CV
iV
iV
iC
CC
CC
CC
CC
CD
P’.-
._0
’.0
‘ —0’
.k)
00
Vi
GO
0’.
‘.0
0’.
Vi
Cb
-.a
Vi
Vi
——
Vi
Vi
Vi
Vi
PP
°V
i-9°’.
—V
i.
CV
iC
‘.0
0’.0
C.
t’J
r
C
cc00
-1‘.
Vi
‘.0
-1...
CV
i0
00’
.C
00
—0
’.00•
I
Vi
00
Vi
——
Vi
—-V
i-
—k)’C
—0’.V
i-IV
i‘.000i-
—.
Vi
4.
ViC
C—
—V
i--a-4
.i--V
iC
Vi
‘‘.0’.
0’.
—.
C0J0
0V
iC
WI’J
Vi’.0
Vi
tJC
00
CC
Vi’.0
Vi00000’.’.000
Vi
00
Vi
Vi
—D
I’J
00
Vi
Vi
‘.0
CV
iV
i—
Vi
-l
Vi
—.
—-
—H
C0’
.V
ii-
’V
iV
i-.
‘J00
Vi
Vi
—k)
i-’
‘3k)
Ct’-
Vi
Vi
Vi
‘.)
—‘.
00
0‘.
0V
iVi
—V
i4J-D
—V
iV
i’i3
-4
——
——
-Q
’.V
iC
C-
flV
i-‘.0
‘.0
‘.0
Vi
0’.
C0’
.‘.
0‘.
00’
.0’
.‘.
00
’.-
t-J
0’.
0’.
‘.0
-..
‘3C
i3:.
boo
00
k)
t’-.)
00
00
C0oJ
CC
C0
CC
00
C.
4‘-
JC
CC
0’.
CV
iC
—.
Vi
Ct I
0 0 0 rJQ O C I.0’
.C
0’.
C’.
.tJ
‘.0
L’J
C0 00
Vi
Vi
Vi
-a C Vi
00
C Vi
C
00 -a cc Vi
C’.
‘.0
Vi cc
00 -a Vi
Vi
—a 0’.
00
Ji -a ‘.0
Vi
‘.0
Vi
Vi
..-
I’..)
0’.
\0
-a
0’.
00
Vi
‘.0
C00
‘—0’.
—V
iV
iV
i4
C’.0
’.0
—aV
iCV
iV
i00
Vi
—k
)t-
J0000
-0’.
00
C’.
Vi
H 0 H
‘I
LJ
JtJ
44
L—
CC
CC
C‘-‘
CC
C-
--
4.—
)—
-‘
W0
00
00
0t’
JC
(J
-1t’
J—
c.)
L’)
t’J
—‘
CC
—0
-J—
C)
—0
C00
—)
I*
(1)C
/)C
,)
00
00
(DC
DC
D
ccO
OV0
CC
0jo_
‘ij
?0
NP
”P’
P’0
—)
C0
-0
00
00
C0
—il
-L
ID
-)00
CC
‘—
C0
0—
CC
i—’
C—
CJ
i-.)
—C
CC
C—‘‘C
CC
CC
C—
—C
—C
-00
(J
‘_
)
‘-
----
PP
PP
PP
PP
PP
PP
PP
t-P
PP
PP
PP
PC
.1.
CC
C—
‘—
—-
CC
0(J
00-
—C
C)
CC
C—
0-
—C
CC
C—
‘a
CC
0C
C0
C‘-
0C
‘CD
-‘
-‘
-‘
-‘
——
——
—C
—-.-
-—
i—’
——
——
—-‘
-‘
-‘
-‘
——
0—
-.0
C-
—C
CO
OC
OC
CC
CQ
CC
CC
CC
CC
CC
oC
b,__,<
—J0U
CC
0(1
)0
‘i-
--
--
--
——
——
C—
——
——
——
——
C—
——
—0
——
C.
00
CC
CC
OC
CC
CC
CC
C’-O
CC
C•C
0C
Cco
‘C
—(
—C
——
t’-)
k)
t-J
i—a
i-J
—-
—I’
-)C
—0
—a
C—
CD‘-
0C
C-l
CW
0t-
JW
-‘
-O
00.
)—
)C
CI’
-)‘t
—400
—_0
cak)—
—a
W-
.a—
i--)
—00
•W—
‘(1
0‘
—a
00
NC
P0
0i-
.)00
—V
N\Q
400
C00
iC
CQ
-C
©b.C
b\
-4-
-4. I
c—i
0c-
i
nz
zzzz
00
00
00
(_)
CC
CC
CC
CDCD
CD
CD
CD
Ct)
II
II
II
II
II
II
II
II
II
II
ICD
k)
L’
CC
Ct’
))
1.)
t’J
tJt’
Jt’
I’)
CDI’.
3C
CC
C‘.
0‘.
0‘.
0‘.
0Q
4G
oGo
00
00
Uv
WC
Lj.)
—G
O4
t’J
C-‘C
——‘C
tJ—‘C
00 C
0 CD CD 0 CD
* CD I I
;I.>
00
0E
CD
Go
CD
L?
——
t3—
I’)
——
——
“3G
oU
CP
-k..
co
w‘.
0G
OC
CDC
CC
CC
CC
OC
C—
CC
CC
C—
CC
CC
CC
CC
CC
—-C
0—
C-
C‘.
3C
—C
C4
UI
Go
‘J
—a
UI
UI
CC
—U
IQ
C‘.
oCD
—
‘-x
CC
CC
CC
00C
CC
CC
pC
Co
C0
CC
•C
JC
t’3
I’.)
3“<
CC
—C
CC
C0
-1.-
UI
‘-3
UI
CC
CU
I4
CC
C4
CCD
——
—C
——
—--—
—0—
-’
0-’
CC
C-‘
C—
——
——
—C
CC
CC
CoC
C0o0ccC
coC
CC
Co
Cco
g.
-.‘
.3‘.
0t-
Jt’
31N
3t)
t.3
>3—
3U
It’
3G
OC
Go
UI
‘.0
-‘
‘.0
-‘
kC
Ct’
3U
IC
Go
0‘
CD
-CD
——
C—
—C
C—
‘—
CC
—C
——
‘—
——
——
C.
CC
C‘.
0‘.0’.0C
’.0C
CC
CC
CC
’.C
1’k)C
CL
30
CC
C—
3’.0
--’’.0---’’.3G
o.E
Go
C>
UI
CU
I—
——
3G
oC
>G
o—
-1U
IG
o-3
CC
cM
——
——
-U
IU
IU
IU
IU
IU
IQ
>G
OU
IO
CC
G0U
IG
0U
I
C•C
.C
0>
I
I
C-)
C.)
C
CDCD
*
Guam Power Authority Distribution Analysis 2010 — 2015
APPENDIX M - T&D Costs
Estimates in this appendix are used to generate Transmission and Distribution installation andlabor costs for Appendices E through K.
$11,065.8? (Includes 10% mark up)* Estimates based on GPA cost program.
T&D Cost to Re-tap 1 Lateral* *
* * * * Estimates based on GPA cost program.
T&D Cost to install 1 switch*
Materials none $ -
Labor 2 man crew for lhr @ $16.64 $ 33.28Equipment Bucket Truck $ 65.00Overhead .25(Labor) X . lO(Materials) $ 8.32TOTAL $ 106.60‘ Estimates assumed are based on T&D recommendations.
T&D Cost to install Capacitor Bank***
450 kVAR Capacitor Bank $ 2,247.47900 kVAR Capacitor Bank $ 2,247.471350 kVAR Capacitor Bank $ 6,493.22
Estimates are based on previous CIP work orders.
T&D Cost to Re-conductor 1-180ft Span****
$1874.96 (Includes 10% mark up)
- 81 -
.Ij
II
II
II
II
II
II
II
II
II
II
II
II
II
II
ICO
k)
t)tN
JL
’)t’
Jt’
Jt’
Jt’
LI)
-.
4— C-
)c
CC
C(tI
- ——C
CC
0C
— -——0
CC
.-
44.
44.
4— 4.-
—a
—a
w00
00
00
0L.
.It-
aC
QU
tIJ
——C
t)I-’
0tJ
-t
—C—0k
)—Ck
)—C.Q
00
—i
I
00
i11-
I.00
00 r
L..I
.ItJ
—.—
.)0
)-
— t. k)
—)
— —4-
t’J
— —-
— —C‘J
400
00
00
IJI
0—
aLI
-)LI
-)O
—1
OC
-0
CC
<I
LIO
1JJ
—a
00
00
00
ci
0— —a—
LI0-
LI-)
—.
II
II
II
II
II
II
II
II
II
II
Il
II
II
II
II
ILI
t-c-
.)4
t-)
t—.)
-t—
t-3
• -t’
3t-
J4
LI)
t—)
4tJ
JC
t’J
CL
.JLI
-‘ViI’J
i—’
.C
CV
iC
C4
—-k
)C
CC
C- CC
t-J
CE’
-J—
—00
——W0
0LI
LI)
—tI
CW
LIC
-C
—-Q’J
C.
— WW— C—
LI4
-J—
a— C0
0C
CC
\0I’-
I.-
‘J
QO
--I’
-)C
I—a
00
——
——
——
——
C)I-
II
II
II
II
II
II
t—)
t-J
)-
.Ik
)W
—L
I)—
COC
C-
t-)
CC
--—
t—.)
Mk)
-‘V
i4
Vi
-k
—k
a-
-.
c,I-
.)—
CV
iI’
J
----—
-—
-—
-—
—
t-a
cC
k)
—.1
-0
—.
Vi
C—
ICI
D0 CD C C-
I)
k)i-
k).-
O)
.4
I-j
-C)
C)_
Vit
IC
CO‘0
COCO
-.‘0
I-I
-.t
000
--.
000
CO
$:.
;t-:
tk
)_
0I
Cl)
—C
)0 )
—00
I00
-
-I-)
Cl)
C-
-0
-.0
0O
I
0)I
—-
CO-
—a
—t’
)
CO
f0’
CO—
CO
-i
I’-)C
0lJi
0)CO
‘J
C)
CCO
0)-
C4
000
C’
-—
a—CO .
—.
-
(-) I
rj
II
II
II
II
II
II
II
II
II
ICD
k)
L’J
CC
Ct’
Jt’
)t)
)CD
L’-)
,)C
00
0‘Q
D0
00
4.
00000000
Ui
Ui
Ui
0-
W—
C-
Ui
—00
CIN
Ji—
’C
-‘
CW
CW
t’J
C
00
cr 0 C
i00
CD j
4U
i-
Ui
Ui
Q—a
-‘
I’-)
Ui
—U
i-
00
0C
—a—
ik
)—
L.
00
0o
CC
—C
0C
——
.1J
—Q
I-”
II
II
II
II
II
II
II
II
II
II
II
II
II
Ik
)‘-
t)t’
JI’
-)C
Ct-
.U
iU
iU
iI
JJ
‘Jt’
)IJ
C‘-
tJt’
Jk)
Ui
‘.)
tJJ
00
0C
CC
CC
CC
C.
0-
——
t.)
0U
i00
Ui
C00
C—
Ui
Ui
CDU
iU
i00
Ui
t——
I’-)
C0
00
0—
I-J
CI’
JU
i)
(-J
- -
CD CD C/)
CD CD
top related