POWER SUPPLY PROCUREMENT PLAN

ORIENTAL MINDORO ELECTRIC COOPERATIVE, INC.

POWER SUPPLY PROCUREMENT PLAN

In compliance with the Department of Energy’s (DOE) Department Circular No. DC 2018-02-0003, “Adopting and
Prescribing the Policy for the Competitive Selection Process in the Procurement by the Distribution Utilities of Power
Supply Agreement for the Captive Market” or the Competitive Selection process (CSP) Policy, the Power Supply
Procurement Plan (PSPP) Report is hereby created, pursuant to the Section 4 of the said Circular.

The PSPP refers to the DUs’ plan for the acquisition of a variety of demand-side and supply-side resources to cost-
effectively meet the electricity needs of its customers. The PSPP is an integral part of the Distribution Utilities’
Distribution Development Plan (DDP) and must be submitted to the Department of Energy with supported Board
Resolution and/or notarized Secretary’s Certificate.

The Third-Party Bids and Awards Committee (TPBAC), Joint TPBAC or Third Party Auctioneer (TPA) shall submit
to the DOE and in the case of Electric Cooperatives (ECs), through the National Electrification Administration (NEA)
the following:

a. Power Supply Procurement Plan;

b. Distribution Impact Study/ Load Flow Analysis conducted that served as the basis of the Terms of Reference; and
c. Due diligence report of the existing generation plant

All Distribution Utilities’ shall follow and submit the attached report to the Department of Energy for posting on the
DOE CSP Portal. For ECs such reports shall be submitted to DOE and NEA. The NEA shall review the submitted
report within ten (10) working days upon receipt prior to its submission to DOE for posting at the DOE CSP Portal.

The content of the PSSP shall be consistent with the DDP. The tables and graph format to be use on the PSPP
report is provided on the following sheets. Further, the PSPP shall contain the following sections:

I. Table of Contents
II. Introduction
III. Energy and Demand Forecast (10 year historical and forecast)
IV. Energy Sales and Purchase
V. Daily Load Profile and Load Duration Curve
VI. Existing Contracts & Existing GenCos due diligence report
VII. Currently approved SAGR for Off-Grid ECs to be passed-on to consumers;
VIII. DU’s Current Supply and Demand
IX. Distribution Impact Study
X. Schedule of Power Supply Procurement
XI. Timeline of the CSP

For inquiries, you may send it at doe.csp@gmail.com or you may contact us through telephone
numbers (02) 840-2173 and (02) 479-2900 local 202.
 POWER SUPPLY PROCUREMENT PLAN

TABLE OF CONTENTS

I. Introduction
II. Energy Sales and Purchase
III. Demand
IV. Load Profile and Load Duration Curve
V. Power Supply Contracts
VI. Distribution Impact Study
VII. Schedule of CSP
VIII. Monthly Data
 POWER SUPPLY PROCUREMENT PLAN

INTRODUCTION
DISTRIBUTION UTILITIES PROFILE
ORMECO, Inc's Franchise MAP
ORMECO, Inc. was established on February 16, 1973 by
virtue of the Republic Act No. 6038 and amended by
Presidential Decree 269 and 1645. It was a government
program for Rural Electrification patterned to National
Rural Electric Cooperative of America (NRECA). The
cooperative structure of ORMECO, Inc. is uncommon
being a non-stock and non-profit form wherein purely
service benefits are being enjoyed by its member-
consumers.

Oriental Mindoro Electric Cooperative, Inc. serves the

fourteen (14) municipalities and one (1) city. The service DUs Franchise Map
area is divided into seven (7) Districts; District 1 – Baco,
San Teodoro, Puerto Galera; District 2 – Calapan City;
District 3 – Naujan, Victoria; District 4 – Socorro, Pola;
District 5 - Pinamalayan, Gloria; District 6 – Bansud,
Bongabong; and District 7 – Roxas, Mansalay, Bulalacao.

As of Decmber 2018, ORMECO, Inc. categorized as

Class AAA - Mega Large cooperative. We have around
185,000 cutomers and a 219,188 out of 220,600
(99.36%) consumer connections.
Number of
Customer
ACTUAL FORECAST
Connections in
Franchise 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028
Residential 164,345 172,023 179,778 187,511 195,171 202,732 210,177 217,498 224,691 231,755 238,693
Commercial 10,369 10,596 10,921 11,273 11,651 12,055 12,486 12,943 13,426 13,936 14,472
Industrial 181 191 202 211 221 229 238 245 253 260 267
Others 4,683 4,814 4,960 5,102 5,239 5,373 5,502 5,628 5,751 5,870 5,987

Total (Captive
179,578 187,625 195,861 204,097 212,282 220,389 228,402 236,314 244,120 251,821 259,418
Customers)

The increase is attributable to the 2018 No. of Customers

continuosly growing number of billed
connections from captive market.

Urbanization and industrialization is

remarkable not only in Calapan City but also
in some of our municipalities.

Commercial buildings, resorts, industries

like rice mill plants, new public buildings are
continously sprouts in the coverage area.
Residential Commercial Industrial Others
 POWER SUPPLY PROCUREMENT PLAN

ENERGY SALES AND PURCHASE

ENERGY SALES HISTORICAL
AND PURCHASE 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018
Energy Sales (MWh) 122,323 136,455 141,867 155,735 169,672 183,780 199,364 216,050 236,614 265,744

Energy Purchase
138,575 153,115 157,191 171,671 187,367 204,740 224,371 243,288 265,477 301,015
(MWh)

System Loss (MWh) 16,215 16,660 15,325 16,593 18,471 21,750 25,007 27,239 28,863 35,271

ENERGY SALES FORECAST

AND PURCHASE 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028
Energy Sales (MWh) 292,582 323,839 357,927 395,044 435,434 479,372 527,147 579,058 635,411 696,515

Energy Purchase
324,974 355,740 389,761 426,463 468,549 514,720 564,804 619,097 678,259 742,295
(MWh)

System Loss (MWh) 32,391 31,901 31,833 31,419 33,114 35,348 37,658 40,039 42,848 45,780

Energy Purchase vs Energy Sales

Energy, MWH

2019 2020 2021 2022 2023 2024 2025 2026 2027 2028
FORECAST
YEARS

Energy Sales (MWh) Energy Purchase (MWh) System Loss (MWh)

Brief Highlight and Report

ORMECO, Inc.'s power providers, five (5) of 11 are all renewable energy suppliers i.e. Linao Cawayan Mini
Hydro Power Plant - Lower, Linao Cawayan Mini Hydro Power Plant - Upper, Inabasan River Mini Hydro
Power Plant, Catuiran Hydro Electric Power Plant and PHESI wind energy power facility and the rest are
all conventional power suppliers i.e. DMCI Power Corporation, Power One Corporation, Ormin Power
Incorporated, Mindoro Grid Corporation - Calapan City, Mindoro Grid Corporation - Bongabong and GBH
Power Resources Incorporated. And the combinations of capacity of those RE providers has equivalent of
32% margin of the grid.
 POWER SUPPLY PROCUREMENT PLAN

Connection to the contract durations, Mindoro Grid Corporation - Calapan City ended it contract last
February 3 2020. While GBH Power Resources Inc. are scheduled on December 15 2020.

After the consecutive devastation of typhoons in Oriental Mindoro and the massive restoration activity,
ORMECO,Inc are now focused on rehabilitation/correction works of the distribution networks and
implementation of the CAPEX programs. This way, we implement those urgent projects of the cooperative
in terms of system loss reductions that is kWHr meter replacements, upgrade of distribution lines,
implementation of transformer load management, uprating and splitting of overloaded transformers and
uprating/upgarding of our power substations.
 POWER SUPPLY PROCUREMENT PLAN

DEMAND
HISTORICAL
Demand
2009 2010 2011 2012 2013 2014 2015 2016 2017 2018
Coincident Peak
28.32 27.00 28.93 30.30 33.52 39.02 42.70 42.27 45.75 52.10
Demand (MW)
Off Peak Demand
nd nd nd nd 10.46 11.94 12.24 11.6 13.55 17.92
(MW)
nd = no data
FORECASTED
Demand
2019 2020 2021 2022 2023 2024 2025 2026 2027 2028
Coincident Peak
56.93 62.14 67.12 71.84 76.30 80.50 84.46 88.21 91.76 95.12
Demand (MW)
Off Peak Demand
18.40 20.08 21.69 23.22 24.66 26.02 27.30 28.51 29.66 30.75
(MW)
56926.3 62135.3 67119.4 71840.7 76296.5 80498.8 84464.6 88212.1 91758.6 95120.6

Coincident Peak Demand vs Off-peak Demand

91.76 95.12
88.21
84.46
80.50
76.30
71.84
67.12
62.14
56.93
MW

27.30 28.51 29.66 30.75

23.22 24.66 26.02
18.40 20.08 21.69

2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
HISTORICAL
Years

Coincident Peak Demand (MW) Off Peak Demand (MW)

Brief highlight of historical demand and forecasting methodology and result

By 2016, the peak demand had been sustained due to decremental effect of TY Nona on December 2015. And due
to continously growing demand of whole province of Oriental Mindoro, we are back in track in terms of growing
demand.

An average of 7% annual growth rate are expected for the next ten years. And a determined spot loads by next 5
years for regional public buildings that will rise in Calapan City and commercial investors in some high potential
municipalities.
 POWER SUPPLY PROCUREMENT PLAN

LOAD PROFILE AND LOAD DURATION CURVE

2018 ORMECO's Hourly Load Profile (MW)

60

50

40

30

20

10

0
1

2542

7162
232
463
694
925
1156
1387
1618
1849
2080
2311

2773
3004
3235
3466
3697
3928
4159
4390
4621
4852
5083
5314
5545
5776
6007
6238
6469
6700
6931

7393
7624
7855
8086
8317
8548
2018 ORMECO's Load Curve
Dry Season
60
52.1
49.8 51.1
48.1 47.9 47.5 48.7 48.2
50 45.7
42.4543.3 41.3 42.1
40.3 40
38.25 38.7
40 35.1534.35 35.55
31.4532.0530.35
29.75
30

20

10

Brief highlight:
Based on the graph above, the ORMECO's marked peak demand last 2018 was 52.10MW and marked off-peak
was 29.75MW during dry months. Based on the records, the system recorded 19.75MW off-peak demand on
February 2018, when most of the tropical depressions that cause southeast moonsoon hit the whole province of
Oriental Mindoro which resulted a cold and rainy season of almost whole month duration.
Based on the graph above, the ORMECO's marked peak demand last 2018 was 52.10MW and marked off-peak
was 29.75MW during dry months. Based on the records, the system recorded 19.75MW off-peak demand on
POWER
February 2018, when most of the tropical SUPPLYthat
depressions PROCUREMENT PLAN
cause southeast moonsoon hit the whole province of
Oriental Mindoro which resulted a cold and rainy season of almost whole month duration.

The graph is erratic against to the other distribution utilities because ORMECO, Inc. belongs to small power utilities
group (SPUG) and to the Small Island / Isolated Grid (SIIG) which more of the customers attended are residentials
and small commercial types.
 POWER SUPPLY PROCUREMENT PLAN

MIX SUPPLY VS DEMAND AND THE OPTIMAL SUPPLY

ACTUAL FORECAST
Supply Demand
2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028
Peak Demand, MW 52.10 56.93 62.14 67.12 71.84 76.30 80.50 84.46 88.21 91.76 95.12
Contracted Capacity, MW 52.50 58.50 59.50 54.50 49.50 49.50 49.50 49.50 49.50 43.10 43.10
LCMHHP LOWER CASCADE 1.20 1.20 1.20 1.20 1.20 1.20 1.20 1.20 1.20 1.20 1.20
LCMHHP UPPER CASCADE 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50
DMCI POWER CORPORATION 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00
POWER ONE CORPORATION 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00
ORMIN POWER INC. 6.40 6.40 6.40 6.40 6.40 6.40 6.40 6.40 6.40 - -
MINDORO GRID CORPORATION CALAPAN CITY 5.00 5.00 - - - - - - - - -
MINDORO GRID CORPORATION BONGABONG 5.00 5.00 5.00 5.00 - - - - - - -
GBH POWER RESOURCE INC. 5.00 5.00 5.00 - - - - - - - -
CATUIRAN HYDRO ELECTRIC POWER PLANT 4.40 4.40 4.40 4.40 4.40 4.40 4.40 4.40 4.40 4.40 4.40
INABASAN RIVER MINI HYDRO POWER PLANT - 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00
PHESI WIND ENERGY POWER FACILITY - - 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00
Uncontracted Demand, MW 0.00 0.00 2.64 12.62 22.34 26.80 31.00 34.96 38.71 48.66 52.02

ACTUAL FORECAST
Supply Demand
2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028
Peak Demand, MW 52.10 56.93 62.14 67.12 71.84 76.30 80.50 84.46 88.21 91.76 95.12
Operating Capacity, MW 48.70 49.30 53.50 49.30 44.30 44.30 44.30 44.30 44.30 37.10 37.10
LCMHHP LOWER CASCADE 0.30 0.30 0.30 0.30 0.30 0.30 0.30 0.30 0.30 0.30 0.30
LCMHHP UPPER CASCADE 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50 0.50
DMCI POWER CORPORATION 13.50 13.50 13.50 13.50 13.50 13.50 13.50 13.50 13.50 13.50 13.50
POWER ONE CORPORATION 9.00 9.00 11.20 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00
ORMIN POWER INC. 6.40 6.20 7.20 7.20 7.20 7.20 7.20 7.20 7.20 - -
MINDORO GRID CORPORATION CALAPAN CITY 5.00 5.00 - - - - - - - - -
MINDORO GRID CORPORATION BONGABONG 5.00 5.00 5.00 5.00 - - - - - - -
GBH POWER RESOURCE INC. 5.00 5.00 5.00 - - - - - - - -
CATUIRAN HYDRO ELECTRIC POWER PLANT 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00
INABASAN RIVER MINI HYDRO POWER PLANT - 0.80 0.80 0.80 0.80 0.80 0.80 0.80 0.80 0.80 0.80
PHESI WIND ENERGY POWER FACILITY - - 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00
Supply for PSA Approval, MW 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
none
Uncontracted Demand, MW 3.40 7.63 8.64 17.82 27.54 32.00 36.20 40.16 43.91 54.66 58.02
 POWER SUPPLY PROCUREMENT PLAN

Supply vs Demand
100.00
90.00
80.00
70.00
60.00
MW

50.00
40.00
30.00
20.00
10.00
0.00
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027
ACTUAL FORECAST
YEARS

Contracted Capacity, MW Uncontracted Demand, MW Peak Demand, MW

List of Existing Contracts and Details
Embedde Net
Contracte Utility-
PSA PSA Contracte Base / d/ Installed Dependab
Plant Owner/ d owned/
Supply Contracted Capacity Factor Effectivity Expiration d Energy, Mid-merit Grid Status Fuel Type Capacity le
Operator Capacity, NPC/ IPP/
(MM/YR) (MM/YR) MWH / Peaking Connecte (MW) Capacity
MW NPC-IPP
d (MW)

Linao Cawayan Commer

Grid
Mini Hydro Base Utility- cial
ORMECO, Inc 45% to 100% 01/12 n/a 1.20 n/a Connect Hydro 2.18 2.10
Power Plant - Load owned Operatio
ed
Lower Cascade n

Linao Cawayan
Mini Hydro Base Embedd Utility-
ORMECO, Inc 45% to 100% 02/15 n/a 1.50 n/a - Hydro 3.24 3.00
Power Plant - Load ed owned
Upper Cascade

Commer
6,570
Power One Base Embedd cial Bunker
POC 70% to 100% 05/12 05/32 9.00 per NPP 15.30 12.40
Corportion Load ed Operatio C Diesel
month
n
 POWER SUPPLY PROCUREMENT PLAN

Commer
3,600
GBH Power Base Embedd cial Bunker
GBH 50% to 100% 12/2000 12/20 5.00 per IPP 7.50 5.20
Resourcs Inc. Load ed Operatio C Diesel
month
n
Commer
4,939.2
Ormin Power Base Embedd cial Bunker
OPI 70% to 100% 11/11 11/26 6.40 per NPP 9.89 7.40
Inc. Load ed Operatio C Diesel
month
n
Commer
Mindoro Grid Base
43,560 Embedd cial
Corporation - MGC 80% to 100% 02/13 02/20 5.00 Load/Re NPP Diesel 10.00 7.60
per year ed Operatio
Calapan City gulating
n
Commer
Mindoro Grid
43,560 Base Embedd cial
Corporation - MGC 80% to 100% 03/13 03/22 5.00 NPP Diesel 15.00 6.50
per year Load ed Operatio
Bongabong
n

MEOT
Base
1,800 per
month /
MEOT
Regulatio
n 1,800 Commer
Base
DMCI Power per Embedd cial Bunker
DMCI 90% to 100% 02/15 02/35 15.00 Load/Re NPP 15.56 15.00
Corporation month ed Operatio C Diesel
except on gulating
n
April and
May
increase
to 5,500
per
month

Commer
Inabasan River 4,083 to Grid
Base cial
Mini Hydro OPI 45% to 100% 01/19 01/44 6.00 4,320 per Connect NPP Hydro 10.00 10.00
month
Load Operatio
Power Plant ed
n
 POWER SUPPLY PROCUREMENT PLAN

Commer
Catuiran Hydro 38,554 Grid
Base cial
Electric Power SPC 45% to 100% 11/18 11/43 4.40 per Connect NPP Hydro 8.80 8.00
Load Operatio
Plant annum ed
n
Commer
PHESI Wind 5,500 Grid
Base cial
Energy Power PHESI 30% to 100% 12/19 12/44 6.00 per Connect NPP Wind 16.00 16.00
Load Operatio
Facility month ed
n

As of December 2018, the Small Grid (69kV Transmission Line) owned by the National Power Corporation is not yet rehabilitated after the hit of TY Nona last
December 2015. The capacity load factors of each IPP/NPP is abnormal and limited due to this situation. In order to supply the needed requirement per
municipalities, we maximized the existing contracts that was tangible and flexible, which is the contract between the Mindoro Grid Corporation whose gensets
are all modular and diesel fueled.

Mid of 2019, it is scheduled to complete the total rehabilitation project of the NPC for their 69kV Transmission Line yet it was energized last January 6, 2020.
We are expecting to a substantial effect to the capacity load factor of each plants. And there will be a great impact on dispatch protocol even on mix
generation capacity due to the participations of the renewable energy suppliers.

In additional, we also provided the forecasted operating capacity of each plant as per reference to their existing net plant dependable capacity. We can refer
to our "Annex Monthly Data for the detail load allocations and dependable capacity versus to the monthly forecast peak demand.

The current Subsidized Approved Generation Rate for Oriental Mindoro is PhP5.6404 per kWHr.
 POWER SUPPLY PROCUREMENT PLAN

DISTRIBUTION IMPACT STUDY

The study mainly focused on creating the most reliable power system model to address the increasing power
demand of the Province and in line to the upcoming expiration of the ESA of GBH Power Resources, Inc. and
Mindoro Grid Corporation (MGC) – Calapan and Bongabong.

The study includes the load demand forecasts covering 2020 to 2024, through Regression Analysis, which are
based on historical data of Distribution Development Plan (DDP), Monthly Financial and Statistical Report
(MFSR), and Feeder data from 2010 to 2018. The study presents load flow, stability, and forecasted demand and
capacity through various simulations using engineering software.

In order to perform a System Impact Study, engineering software will simulate the ORMECO, Inc. power system
model for appropriate representation of load and generation for the five year time frame/forecasts. These models
will include existing transmission line and IPPs, as well as the incoming IPPs with installed plant capacity of 16
MW and dependable capacity of 6 MW and outgoing IPP’s with installed plant capacity of 32.5MW and total
dependable capacity of 21MW.

This study limits on the load demand and the dependable capacity forecast from the year 2020 to 2024, the
additional capacity needed per year, and the location of each proposed additional power producers in the
province of Oriental Mindoro.

Recommendations

• The proposed power providers should be an open type technology and must deliver the needed dependable
capacity of 30MW in 2021 as mid-merit and peaking type of power plant and 10MW in 2024 as base load type of
power plant located at the Southern part of Oriental Mindoro.
• Fault Circuit Analysis and Distribution System’s Overcurrent Protection on and Coordination should be
performed for the enhancement of ORMECO’s present distribution system.
• Conduct Feasibility Study with regard to Economic Impact of the upcoming power providers in order to identify
the type of required power plant technology.
• Optimal and strategic placement of new substations across the province must be considered.
• To support the addition of power plants stated above , the following modifications are recommended from 2020
to 2024:
• Installation of new substation in Mansalay with 5MVA power transformers to unload the 5MVA power
transformer of Roxas
• Installation of new substation in Calapan City with 50MVA power transformers to unload the 20 MVA power
transformer of NPC
• Additional 5 MVA and 10MVA power transformer in Naujan and Pinamalayan substation, respectively.
• Re-conductoring of feeder lines must be prioritized.
POWER SUPPLY PROCUREMENT PLAN
 POWER SUPPLY PROCUREMENT PLAN

SCHEDULE OF CSP

Proposed contract
For CSP Proposed schedule (MM/YYYY)
period (MM/YYYY)
Base / mid-
merit / Publication Submissio
Joint
peaking Demand Energy Start Month End Month of Pre-bid n and Bid PSA
Awarding Application
(MW) (MWh) and Year and Year Invitation Conference Opening of Evaluation Signing
to ERC
to Bid Bids
Mid-merit/
30.0* 1-Mar-22** 1-Mar-37 1-Jul-20 22-Jul-20 20-Sep-20 27-Sep-20 20-Oct-20 19-Nov-20 28-Nov-20
Base
xxxxx

Note: * - The 30.0MW installed capacity, Open Type Technology with a Mid-Merit/Base capable Power Plant.
** - The proposed contract period will be 15 year duration which will start on March 2022. It also means that there will be an Interim Power Supply
agreement(which will be indicated in the propose Term of Referrence of CSP) which are expected to deliver during the construction of the
30MW main power plant.
 POWER SUPPLY PROCUREMENT PLAN

10 Year Monthly Data

Contracted and For
PSA Approval Energy Uncontracted Demand Committed for
Forecast
and Operating and Energy CSP
Demand
Year
Coincide Uncontr
Off Peak Energy Uncontracte
nt Peak Demand Energy acted Demand Energy
Demand Requirement d Energy
Demand (MW) (MWh) Demand (MW) (MWh)
(MW) (MWh) (MWh)
(MW) (MW)

2019
Jan 47.15 18.40 23,759.83 64.40 35,473.03 17.25 (11,713.21)
Feb 47.64 21.05 24,045.10 64.40 35,473.03 16.76 (11,427.93)
Mar 50.86 22.70 24,044.17 49.30 35,473.03 (1.56) (11,428.86)
Apr 54.96 27.40 27,596.93 49.30 39,173.03 (5.66) (11,576.11)
May 56.93 28.90 29,414.56 49.30 39,173.03 (7.63) (9,758.48)
Jun 54.63 24.70 28,974.80 49.30 35,473.03 (5.33) (6,498.24)
Jul 50.64 29.90 26,128.33 54.90 35,473.03 4.26 (9,344.71)
Aug 51.79 24.80 27,616.40 54.90 35,473.03 3.11 (7,856.64)
Sep 55.72 21.50 28,240.14 57.90 35,473.03 2.18 (7,232.89)
Oct 53.48 23.00 29,740.80 57.90 40,973.03 4.42 (11,232.24)
Nov 51.41 23.80 28,968.49 57.90 40,973.03 6.49 (12,004.55)
Dec 52.23 24.50 26,444.25 57.90 40,973.03 5.67 (14,528.79)
2020
Jan 51.46 20.08 26,009.22 64.97 40,973.03 13.51 (14,963.82)
Feb 52.00 22.98 26,321.50 62.60 40,973.03 10.60 (14,651.53)
Mar 55.52 24.78 26,320.48 50.50 37,343.03 (5.02) (11,022.55)
Apr 59.99 29.91 30,209.58 53.50 41,043.03 (6.49) (10,833.45)
May 62.14 31.54 32,199.29 53.50 41,043.03 (8.64) (8,843.74)
Jun 59.63 26.96 31,717.90 49.50 37,343.03 (10.13) (5,625.14)
Jul 55.28 32.64 28,601.95 55.40 37,343.03 0.12 (8,741.09)
Aug 56.53 27.07 30,230.90 55.40 37,343.03 (1.13) (7,112.14)
Sep 60.82 23.47 30,913.69 55.00 37,343.03 (5.82) (6,429.34)
Oct 58.38 25.10 32,556.42 55.00 37,343.03 (3.38) (4,786.62)
Nov 56.11 25.98 31,710.99 55.00 37,343.03 (1.11) (5,632.04)
Dec 57.01 26.74 28,947.78 52.80 37,343.03 (4.21) (8,395.26)
2021
Jan 55.59 21.69 28,496.58 57.20 37,343.03 1.61 (8,846.45)
Feb 56.17 24.82 28,838.73 58.40 33,743.03 2.23 (4,904.30)
Mar 59.97 26.76 28,837.61 46.30 33,743.03 (13.67) (4,905.42)
Apr 64.80 32.31 33,098.65 49.30 37,443.03 (15.50) (4,344.38)
May 67.12 34.07 35,278.64 49.30 37,443.03 (17.82) (2,164.39)
Jun 64.41 29.12 34,751.21 45.30 33,743.03 (19.11) 1,008.17
Jul 59.71 35.25 31,337.27 51.20 33,743.03 (8.51) (2,405.77)
Aug 61.06 29.24 33,122.00 51.20 33,743.03 (9.86) (621.03)
Sep 65.70 25.35 33,870.09 51.20 33,743.03 (14.50) 127.06
Oct 63.06 27.12 35,669.92 51.20 33,743.03 (11.86) 1,926.89
Nov 60.61 28.06 34,743.64 51.20 33,743.03 (9.41) 1,000.61
Dec 61.58 28.89 31,716.17 50.00 33,743.03 (11.58) (2,026.86)
 POWER SUPPLY PROCUREMENT PLAN

2022
Jan 59.50 23.22 31,180.02 57.20 33,743.03 (2.30) (2,563.01)
Feb 60.12 26.56 31,554.39 57.40 33,743.03 (2.72) (2,188.64)
Mar 64.19 28.65 31,553.17 49.30 33,743.03 (14.89) (2,189.87)
Apr 69.36 34.58 36,215.45 44.30 33,813.03 (25.06) 2,402.42
May 71.84 36.47 38,600.73 44.30 33,813.03 (27.54) 4,787.69
Jun 68.94 31.17 38,023.63 40.80 30,113.03 (28.14) 7,910.59
Jul 63.91 37.73 34,288.20 46.20 30,113.03 (17.71) 4,175.17
Aug 65.36 31.30 36,241.00 46.20 30,113.03 (19.16) 6,127.97
Sep 70.32 27.13 37,059.54 46.20 30,113.03 (24.12) 6,946.51
Oct 67.50 29.03 39,028.85 46.20 30,113.03 (21.30) 8,915.82
Nov 64.88 30.04 38,015.35 46.20 30,113.03 (18.68) 7,902.31
Dec 65.91 30.92 34,702.79 45.00 30,113.03 (20.91) 4,589.75
2023
Jan 63.19 24.66 34,257.02 54.20 30,113.03 (8.99) 4,143.99
Feb 63.85 28.21 34,668.34 55.40 30,113.03 (8.45) 4,555.30
Mar 68.17 30.42 34,666.99 44.30 30,113.03 (23.87) 4,553.96
Apr 73.66 36.72 39,789.37 44.30 33,813.03 (29.36) 5,976.34
May 76.30 38.73 42,410.04 44.30 33,813.03 (32.00) 8,597.01
Jun 73.22 33.10 41,775.99 40.80 30,113.03 (32.42) 11,662.96
Jul 67.88 40.07 37,671.94 46.20 30,113.03 (21.68) 7,558.90
Aug 69.41 33.24 39,817.45 46.20 30,113.03 (23.21) 9,704.41
Sep 74.69 28.82 40,716.76 46.20 30,113.03 (28.49) 10,603.73
Oct 71.68 30.83 42,880.41 46.20 30,113.03 (25.48) 12,767.38
Nov 68.90 31.90 41,766.89 46.20 30,113.03 (22.70) 11,653.86
Dec 70.00 32.84 38,127.43 45.00 30,113.03 (25.00) 8,014.40
2024
Jan 66.67 26.02 37,632.75 54.20 30,113.03 (12.47) 7,519.72
Feb 67.37 29.77 38,084.60 55.40 30,113.03 (11.97) 7,971.57
Mar 71.92 32.10 38,083.12 44.30 30,113.03 (27.62) 7,970.09
Apr 77.72 38.75 43,710.27 44.30 33,813.03 (33.42) 9,897.24
May 80.50 40.87 46,589.18 44.30 33,813.03 (36.20) 12,776.15
Jun 77.25 34.93 45,892.65 40.80 30,113.03 (36.45) 15,779.62
Jul 71.61 42.28 41,384.18 46.20 30,113.03 (25.41) 11,271.14
Aug 73.24 35.07 43,741.11 46.20 30,113.03 (27.04) 13,628.07
Sep 78.80 30.40 44,729.04 46.20 30,113.03 (32.60) 14,616.01
Oct 75.63 32.52 47,105.91 46.20 30,113.03 (29.43) 16,992.87
Nov 72.70 33.66 45,882.66 46.20 30,113.03 (26.50) 15,769.62
Dec 73.85 34.65 41,884.56 45.00 30,113.03 (28.85) 11,771.53
2025
Jan 69.95 27.30 41,294.58 54.20 30,113.03 (15.75) 11,181.55
Feb 70.68 31.23 41,790.39 55.40 30,113.03 (15.28) 11,677.36
Mar 75.47 33.68 41,788.78 44.30 30,113.03 (31.17) 11,675.74
Apr 81.55 40.65 47,963.47 44.30 33,813.03 (37.25) 14,150.43
May 84.46 42.88 51,122.51 44.30 33,813.03 (40.16) 17,309.47
Jun 81.06 36.65 50,358.20 40.80 30,113.03 (40.26) 20,245.17
Jul 75.14 44.36 45,411.04 46.20 30,113.03 (28.94) 15,298.00
Aug 76.84 36.80 47,997.30 46.20 30,113.03 (30.64) 17,884.27
Sep 82.68 31.90 49,081.37 46.20 30,113.03 (36.48) 18,968.34
Oct 79.36 34.13 51,689.51 46.20 30,113.03 (33.16) 21,576.48
Nov 76.28 35.31 50,347.24 46.20 30,113.03 (30.08) 20,234.20
 POWER SUPPLY PROCUREMENT PLAN

Dec 77.49 36.35 45,960.11 45.00 30,113.03 (32.49) 15,847.07

2026
Jan 73.06 28.51 45,264.09 54.20 30,113.03 (18.86) 15,151.06
Feb 73.82 32.62 45,807.56 55.40 30,113.03 (18.42) 15,694.53
Mar 78.82 35.18 45,805.79 44.30 30,113.03 (34.52) 15,692.76
Apr 85.16 42.46 52,574.03 44.30 33,813.03 (40.86) 18,761.00
May 88.21 44.78 56,036.74 44.30 33,813.03 (43.91) 22,223.71
Jun 84.66 38.27 55,198.96 40.80 30,113.03 (43.86) 25,085.93
Jul 78.48 46.33 49,776.25 46.20 30,113.03 (32.28) 19,663.21
Aug 80.25 38.43 52,611.12 46.20 30,113.03 (34.05) 22,498.09
Sep 86.35 33.32 53,799.40 46.20 30,113.03 (40.15) 23,686.37
Oct 82.88 35.64 56,658.25 46.20 30,113.03 (36.68) 26,545.22
Nov 79.66 36.88 55,186.95 46.20 30,113.03 (33.46) 25,073.91
Dec 80.93 37.96 50,378.10 39.00 25,173.83 (41.93) 25,204.26
2027
Jan 76.00 29.66 49,589.60 48.20 25,173.83 (27.80) 24,415.77
Feb 76.79 33.93 50,185.01 48.20 25,173.83 (28.59) 25,011.17
Mar 81.98 36.59 50,183.06 37.10 25,173.83 (44.88) 25,009.23
Apr 88.59 44.17 57,598.09 37.10 28,873.83 (51.49) 28,724.26
May 91.76 46.58 61,391.70 37.10 28,873.83 (54.66) 32,517.87
Jun 88.06 39.81 60,473.86 33.60 25,173.83 (54.46) 35,300.03
Jul 81.63 48.20 54,532.94 39.00 25,173.83 (42.63) 29,359.11
Aug 83.48 39.97 57,638.73 39.00 25,173.83 (44.48) 32,464.89
Sep 89.82 34.66 58,940.55 39.00 25,173.83 (50.82) 33,766.72
Oct 86.21 37.07 62,072.60 39.00 25,173.83 (47.21) 36,898.77
Nov 82.86 38.36 60,460.70 39.00 25,173.83 (43.86) 35,286.86
Dec 84.19 39.49 55,192.31 39.00 25,173.83 (45.19) 30,018.47
2028
Jan 78.78 30.75 54,271.48 48.20 25,173.83 (30.58) 29,097.65
Feb 79.60 35.17 54,923.10 48.20 25,173.83 (31.40) 29,749.27
Mar 84.99 37.93 54,920.97 37.10 25,173.83 (47.89) 29,747.14
Apr 91.83 45.78 63,036.07 37.10 28,873.83 (54.73) 34,162.24
May 95.12 48.29 67,187.85 37.10 28,873.83 (58.02) 38,314.02
Jun 91.29 41.27 66,183.36 35.60 25,173.83 (55.69) 41,009.52
Jul 84.62 49.96 59,681.54 39.00 25,173.83 (45.62) 34,507.70
Aug 86.54 41.44 63,080.54 39.00 25,173.83 (47.54) 37,906.71
Sep 93.11 35.93 64,505.28 39.00 25,173.83 (54.11) 39,331.45
Oct 89.37 38.43 67,933.03 39.00 25,173.83 (50.37) 42,759.20
Nov 85.90 39.77 66,168.95 39.00 25,173.83 (46.90) 40,995.11
Dec 87.27 40.94 60,403.15 39.00 25,173.83 (48.27) 35,229.32