�EE116D/E06
Group Members:
FERNANDO, RAM F.
HIDALGO, MARIANNE NICOLE
INFANTE, RENZ D.
GUIMARAS ISLAND POWER PLANT DESIGN
Instructor:
Engr. Jesusito Sulit
Course/Section:
EE116D/EO6
GROUP 5
Adviser:
Engr. Jesus Martinez
Objectives
GUIMARAS ISLAND
Chapter 1
Demographics
Guimaras is a province in the Philippines situated in the Western Visayas region occupying the western section of the Visayas. Its capital is the Municipality of Jordan.
The province has a land area of 604.57 square kilometers or 233.43 square miles. Its population as determined by the 2015 Census was 174,613. This represented 2.32% of the total population of the Western Visayas region, 0.90% of the overall population of the Visayas island group, or 0.17% of the entire population of the Philippines. Based on these figures, the population density is computed at 289 inhabitants per square kilometer or 748 inhabitants per square mile.
Guimaras province is an island ecosystem composed of five coastal municipalities which covers a land area of 60,547 hectares. The topography of Guimaras Island varies from level to steeply sloping with land elevation ranging from 0 to nearly 300 meters above sea level. Mt. Dinalman, located in Millan, Sibunag, has the highest elevation of 267 meters above mean sea level. A simplified topographic contour map indicates that the great part of islands land area is above 100 masl. By comparing the topographic features from the 1956 topographic maps with the present situation, it could be concluded that the island topography has not been altered much by man-made activities. The island’s topography shows quite steep slopes on the western side of island with plateaus and peaks above 200 m in the central portion. A large part or 69% of the total land area is within the 0-18% slope, 19.73% is above 18-30% slope, 9.42% is above 30-50% slope and 1.74 percent is above 50% slope.
Population
Source:
Table 1.2 Total Population and Breakdown from 2OOO-2O15
Population Per Barangay
Source:
Historical, Actual/Potential Electricity Demand
Figure 1.C. Guimaras Island Electricity Demand Statistics DDP 2O15-2O25
Historical, Actual/Potential Electricity Demand
Figure 1.D Guimaras Island Electricity Supply&Demand Statistics
Historical, Actual/Potential Electricity Demand
Figure 1.E Capital Expenditures and Energy Sales
Historical, Actual/Potential Electricity Demand
Figure 1.F Basic Statistics and Highlight
Line of Drive
The group had chosen to follow the recommendations given in their recent DDP Assessment including the locations of the said substation in Brgy. San Miguel and two (2) RE resource in the franchise area.
Population Analysis
Table 1.4 Summary of Projections for 1O years mark
*Population Actual Values based on:
*Projection Tool used :
MS Excel , Regression Analysis
*Values on red:
Projected Value for Financial and Design Analysis
Projected Demand
Table 1.4 Summary of Projections for 1O years mark
*Actual Values based on:
*Projection Tool used :
MS Excel , Linear Regression
*Value on red:
Projected Value for Financial and Design Analysis
Figure 1.J Population Projection
Figure 1.K Energy Sales MWh Projection
Figure 1.L Supply-Demand MW Projection
In conclusion, from 2O16, the actual peak demand is 6.69%, whereas to the year 2O25, the peak demand projection will be up to 9.92% as projected of the DDP 2O17-2O26. The growth rate increased almost 2O% from the previous DDP. There will be a need of at least 3.3% of MWH increase to suffice the 9.92MW demand. In the end of year 2O26, a 1O.8MW of power is needed.
The group will design a power plant of 16MW of power output, which is a combination of a Natural and an RE power plant. The 16MW output is decided, to cover up the power losses of the system including the peak-demand spike of consumers throughout the years as for N-1 Contingencies as well.
Historical Data and Projection Analysis
Chapter 2
PROJECT FINANCIAL ANALYSIS AND RATES DESIGN
Table 2.1 Main Factors to Consider
Density = population/HH =198,036.44/50,489= 3.92
No. households = 50,489HH
Typical hh consumption = average of guimelco = 55.00 kw/mo
Total household consumption =typical hh consumption*no of household =
50,489*55 = 2,776,895 KWh/month
Total island consumption = total hh consumption / %hh over total=
2,776,895/ 75% = 3,702,526.667 KWh/mo
System Load Factor = ave. demand load( of yr 2O26)/peak demand load=
5.28/10.28*100 = 51.36%
Coincident demand = total island consumption / (load factor*730) =
3, 702,526.667/ (51.36%*730) = 9,875.30 kwh/mo
Diversity Factor = 1.05
Non-coincident demand= diversity factor * coincident demand =
1.05 * 9,875.30= 10,369. 07 kWh/mo
PROJECT FINANCIAL ANALYSIS AND RATES DESIGN
II. Project Financial Analysis & Design Impacts
PMW Diesel Power Plant = 2 MW * 5 unit = 10 MW
PMW Mini Hydro Power Plant = 1 MW * 6 unit = 6 MW
PMW TOTAL = Diesel Power Plant + Mini Hydro = 16 MW
%Reserve = (PTOTAL *1000)-(coincident demand) / coincident demand)*1OO = 54.31 %
II. Project Financial Analysis & Design Impacts
Annual Customer Consumption*12 = 3,702,526.667 KWh/mo *12mo = 44,430,320/yr
Mini Hydro Power Plant
Production hours = mini hydro plant factor*(24x365) = 30.00% *8760 = 2,628.00 hrs
kWh/yr (mini hydro) = production hrs * total MW * 1000 = 2,628.00 * 6 * 1000 = 15,768,000.00 kWh/yr
Diesel Power Plant
kWh/yr (Diesel) = annual customer consumption – kWh/yr(mini hydro) = 44,430,320 kWh/yr - 15,768,000.00 kWh/yr = 28,662,320kWh/yr
Production hours = kWh/yr(diesel) / (diesel capacity*1000) = 28,662,320kWh/yr / (10*1000) = 2,866.232hrs
II. Project Financial Analysis & Design Impacts
Total $ (diesel) = fuel cost ($/kW) * total MW (diesel) * 1000
= 1,304* 10 * 1000
= $13,040,000.00
Total $ (mini hydro) = mini hydro cost ($/kW) * total MW (mini hydro) * 1000
= 2,318.52 * 6 * 1000
= $13,911,120.00
Total Php (diesel) = Fuel $ * exchange rate
= 13,040,000.00* 50.84
= Php 662,953,600.00
Total Php (mini hydro) = Mini hydro $ * exchange rate
= 13,911,120.11* 50.84
= Php 707,241,341�
Total Php = total diesel + total mini hydro
= 512,049,700.00 + 718,787,11
= Php 1,370,194,941
II. Project Financial Analysis & Design Impacts
Fuel Cost diesel (Php/kWh) = 50.84 (Fuel Cost $ / MMBTU (coal) * Heat Rate BTU/kWh(diesel) / 1000000 = 50.84(24*9773)/1000000 = 11.9246
Fuel Cost mini hydro (Php/kWh) = 50.84 (Fuel Cost $ / MMBTU (coal)*Heat Rate BTU/kWh(mini hydro) /100000 = 50.84 (0)/1000000 = 0.00
II. Project Financial Analysis & Design Impacts
Diesel Power Plant
% O&M (diesel)= O&M ($/kW) diesel / $/kW(diesel) =42.1/1,304= 3.23%�O&M cost/year (diesel) = total pesos (diesel) * %O&M diesel = 662,953,600* 3.23% = Php 21,403,640/yr
Mini Hydro Power Plant
% O&M (Mini Hydro)= O&M ($/kW) Mini Hydro / $/kW Mini Hydro=52/2,319 = 2.24%�O&M cost/year (mini hydro) = total pesos (mini hydro) * %O&M mini hydro = 707,241,341* 2.24% = Php 15,862,080/yr
II. Project Financial Analysis & Design Impacts
Fuel (diesel) = Fuel cost (php/kwh) *kWh/yr (diesel)
= 11.92* 28,662,320.00
= Php 341,787,380/yr
Fuel (mini hydro) = Fuel cost (php/kwh) *kWh/yr (mini hydro)
= 0*15,768,000.00
= Php 0/yr
Variable O&M (diesel) = 21,403,640*0.3= Php 6,421,092/yr
Variable O&M (mini hydro) = 15,862,080*0.3= Php 4,758,624/yr
Total Capital (diesel) = fuel + variable O&M
341,787,380+ 6,421,092
= Php 348,208,472/yr
Total Capital (mini hydro) = fuel + variable O&M
= 0 + 4,758,624
= Php 4,758,624/yr
2 months working capital = Total capital (diesel + mini hydro) * 2/12
= Php 58,827,849
II. Project Financial Analysis & Design Impacts
Depreciation (diesel) = total php cost (diesel) / life (diesel) = 662,953,600/25 = Php 26,518,144/yr
Depreciation (mini hydro) = total php cost (mini hydro) / life (mini hydro) = 707,241,341/50 = Php 14,144,827/yr
Fixed (diesel) = O&M cost (diesel)*(0.7) = 21,403,640* 0.7 = Php 14,982,548.00/yr
Fixed (mini hydro) = O&M cost (mini hydro)*(0.7) = 15,862,080* 0.7 = Php 11,103,456.00/yr
II. Project Financial Analysis & Design Impacts
Total investment cost = investment cost (diesel + mini hydro) = 662,953,600+707,241,341 = Php 1,370,194,941/ yr
1 month work capital =total working capital (diesel) = 348,208,472*(1/12) = Php 29,017,373
Total work capital allowance = 29,017,373+ 396,552.0 = Php 29,413,924.6/yr
Total plants in service = total (investment cost + work capital allowance) = 691,970,973
RORB 12% = total plants in service *12% = Php 83,036,517/yr
II. Project Financial Analysis & Design Impacts
Total fixed cost (Diesel) = Dep+Fixed O&M+RORB (diesel) =26,518,144+14,982,548+83,036,517 = Php 124,537,209/yr
Total fixed cost (mini hydro) = Dep+FixedO&M+RORB (mini hydro) =14,144,827+11,103,456+84,916,547 = Php 110,164,830/yr
Total fixed cost = total fixed cost (diesel+mini hydro) = 40,662,971+26,086,004+167,953,064 = Php 234,702,039/yr
II. Project Financial Analysis & Design Impacts
Total fuel cost = 341,787,380+ 0 = Php 341,787,380
Total variable O&M = 6,421,092+ 4,758,624= Php 11,179,716
Total Variable Costs = total fuel costs + variable costs = 348,208,472+ 4,758,624= Php 352,967,096
II. Project Financial Analysis & Design Impacts
Total costs (diesel) = total fixed costs (diesel) + total variable costs (diesel) = Php 472,745,680.51
Total costs (mini hydro) = total fixed cost (mini hydro) + total variable cost (mini hydro) = Php 114,923,453.95
Total cost = total cost (diesel + mini hydro) = Php 587,669,134.47
Avg (diesel) = total cost (diesel)/ Kwh/yr (diesel) = 472,745,680.51/28,662,320.00= 16.49
Avg (mini hydro) = total cost (mini hydro)/ Kwh/yr (mini hydro) = 114,923,453.95/ 15,768,000.00= 7.29
Average = total cost/ Kwh/yr = 587,669,134.47/44,430,320.00= 13.23
II. Project Financial Analysis & Design Impacts
Table 2.14 Power Rating Computation
Variable Cost = Total Variable Cost= Php 352,967,095.80
kWh = Total kWh= Php 44,430,320.00
Fixed Cost = Total Fixed Cost= Php 234,702,038.67
Energy charge = variable cost/kWh = Php 7.9443
kW-mo = coincident demand*12= 10,369.07*12=124,428.79 kW-mo
Demand charge = fixed cost/kW-mo = Php 1,886.24/kW-mo
II. Project Financial Analysis & Design Impacts
For Customer A:
kW demand = energy consumed / load factor *730 = 1,000,000/.30*730
= 4,566.21 kW
Energy charge A = Energy charge * energy consumed
= 7,944,284.35* 1,000,000
= Php 7,944,284.35
Demand charge A = Demand charge * kW demand
= 1,886.24*4,566.21
= Php 8,612,949.13/kW- mo
Total Bill = Energy charge A + Demand charge A = Php 16,557,233.48
Average Bill = total bill/Energy consumed
= 16,557,233.48/1,000,000
= 16.56
II. Project Financial Analysis & Design Impacts
For Customer B:
kW demand = energy consumed / load factor *730
= 1,000,000/.54*730
= 2,536.78 kW
Energy charge B = Energy charge * energy consumed
= 1,000,000 * 7.9443
= Php 7,944,284.35
Demand charge B = Demand charge * kW demand
= 2,536.78*1,886.24
= Php 4,784,971.74/kW- mo
Total Bill = Energy charge B + Demand charge B = 7,944,284.35+ 4,784,971.74
= Php 12,729,256.09
Average Bill = total bill/Energy consumed
= 12,729,256.09/1,000,000
= 12.73
II. Project Financial Analysis & Design Impacts
For Customer C:
kW demand = energy consumed / load factor *730
= 1,000,000/.85*730
= 1,611.60 kW
Energy charge C = Energy charge * energy consumed
= 1,000,000 * 7.9443
= Php 7,944,284.35
Demand charge C = Demand charge * kW demand
= 1,886.24* 1,611.60
= Php 3,039,864.40/kW- mo
Total Bill = Energy charge C + Demand charge C
= Php 10,984,148.75
Average Bill = total bill/Energy consumed
= 10,984,148.75/1,000,000
= 10.98
II. Project Financial Analysis & Design Impacts
Net Operating Revenues = Gross revenue-Operating Expenses-Interest Expense
= 587,669,134.47- 393,630,066.61-58,783,572.35
= Php 135,255,495.51
Income Tax (30% net operating rev) = Net operating rev * 30%
= 135,255,495.51*.3
= Php 40,576,648.65
Net Income after Tax = Net Operating Revenues - Income Tax (30% net operating rev)
=135,255,495.51– 40,576,648.65
= Php 94,678,846.85
Equity (30% of plants in service) = Total plants in service * 30%
= 1,399,608,865* 0.3
=Php 419,882,659.63
Return on Equity = net income/equity
= 94,678,846.85/419,882,659.63
= 22.55%
Gross Revenues = Total Fixed + Variable Cost =234,702,039+ 352,967,096 = 587,669,134.47
Operating expenses = Total variable costs + Depreciation = 352,967,096+40,662,971 = Php 393,630,066.61
Interest Expense (6% on 70%) = Total plants in service*70%*6% = 1,399,608,865*0.7*.06= Php 58,783,572.35
II. Project Financial Analysis & Design Impacts
Net Operating Revenues = Gross revenue-Operating Expenses-Interest Expense = 587,669,134.47- 393,630,066.61-58,783,572.35
= Php 135,255,495.51
Income Tax (30% net operating rev) = Net operating rev * 30% = 135,255,495.51*.3 = Php 40,576,648.65
Net Income after Tax = Net Operating Revenues - Income Tax (30% net operating rev) =135,255,495.51– 40,576,648.65 = Php 94,678,846.85
Equity (30% of plants in service) = Total plants in service * 30% = 1,399,608,865* 0.3 = Php 419,882,659.63
Return on Equity = net income/equity = 94,678,846.85/419,882,659.63= 22.55%
CHAPTER 4
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
PROTECTION (Layer 1)
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
PROTECTION (Layer 1)
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
PROTECTION (Layer 1)
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
PROTECTION DEVICES
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
MONITORING (Layer 2)
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
MONITORING (Layer 2)
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
MEASUREMENT (Layer 3)
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
MEASUREMENT DEVICES
TESTING, PRESENTATION, AND INTERPRETATION OF DATA
SPECIFICATIONS/DEFINITIONS
Layer 1 : PROTECTION SYSTEM
Layer 3 : MEASURING SYSTEM
Layer 2 : MONITORING SYSTEM
ANSI/ IEEE Standard C37.2
According to ANSI, “In the design of electrical power systems, the ANSI standard device numbers (ANSI /IEEE Standard C37.2 Standard for Electrical Power System Device Function Numbers, Acronyms, and Contact Designations ) identifies the features of a protective device such as a relay or circuit breaker. These types of devices protect electrical systems and components from damage when an unwanted event occurs, such as an electrical fault. Device numbers are used to identify the functions of devices shown on a schematic diagram. Function descriptions are given in the standard.”
IEEE AND ANSI STANDARDS
ENGINEERING STANDARD
IEEE AND ANSI STANDARDS
ADVANTAGES AND DISADVANTAGES OF POWER PLANTS
IEEE AND ANSI STANDARDS
DIESEL POWER PLANT LOCATION
The proposed Diesel Power plant location is in the center municipality of Millan, Sibunag. There would be 5 units with 1OMW will be installed. The factors being considered are the following:
MINI HYDRO POWER PLANT LOCATION
The proposed Mini Hydro Power plant location would also be in Sibunag, barangay Ravina. There would be 6 units of 1MW capacity will be installed The factors being considered are the following:
CONCLUSION
The future researchers may consider designing wind powerplants, solar and biomass power plants as secondary RE sources. Wind power plants would be the group’s third option if permitted because of the topographical and elevation of the island. The group had chosen to utilize Diesel and Mini Hydro because it can be done, and resources are already available plus the topography is ideal. Guimaras Island is expandable and can be adaptive to many types of power production in the future.
RECOMMENDATIONS
The future groups can approach or contact the said region or Island for its population, GDP and other statistical data they have for less-hassle projection of design. This is because it takes ample time in searching for legitimate and up to date information in the internet alone.
SAMPLE CATALOGUES AND OTHER SECIFICATIONS
SAMPLE CATALOGUES AND OTHER SECIFICATIONS
SAMPLE REFERENCES
END