Techno-Economic Analysis of Commercial Size Grid-Connected Rooftop Solar PV Systems in Malaysia under the NEM 3.0 Scheme

Abstract

Commercial grid-connected rooftop solar PV systems are widely applied worldwide as part of affordable and clean energy initiatives and viable long-term solutions for energy security. This is particularly true in a crowded city where space is a constraint and at the same time, there are unutilized rooftops. With the recently announced Net Energy Metering (NEM) 3.0, commercial buildings in Malaysia can apply up to 75% capacity of the maximum demand (MD), which can be connected to the grid. Apart from reducing electricity bills, the owner can offset energy for 10 years. This paper presents a design analysis with the details of the sizing of a rooftop PV system. The PVsyst software tool is used to estimate the energy produced by a 380 kWp system, and this study provides a financial analysis to evaluate the profitability of the system with a particular interest in commercial buildings under the NEM 3.0 policy, which has resulted in 8.4 years return of investment (ROI). PVsyst is a software used to size the PV system and provides technical, financial, and environmental analysis. This in-depth analysis could provide a useful case study for asset owners in deciding the way forward for sustainable energy production, cost saving, and combating the energy security issue, since Malaysia is blessed with an abundance of sunshine throughout the year.

1. Introduction

1.1. Motivation

Energy plays a key role in the advancement and development of human activity and a brighter future. However, the current energy supply is not enough to cover the demand in the coming years, and it causes damage to the environment [1]. Solar energy is an abundant green source that can replace fossil fuel. Since the sun is available everywhere, solar energy is widely used by most countries, including developing countries. It is used in Malaysia under various government policies. These policies are implemented to encourage the use of green energy and support small and large projects [2,3]. Most implemented PV system are residential or large-scale PV system in Malaysia. Under NEM, residential fill in most of the quota.

Hybrid PV systems are not a popular practice in Malaysia. Due to the lack of analysis proving the variability of implementing a system that can satisfy the electrical needs of the consumer and at the same time reduce the cost of electricity, the consumer pays yearly. NEM 3.0 approved a rooftop PV system implementation that is connected to the utility grid for commercial buildings. The consumer that falls under this category only is able to implement 75% of the maximum demand according to the size of the PV power plant. This gives the motivation to test this policy profitability financially and assess its technical and environmental impact.

1.2. Brief on Solar PV Policies in Malaysia

Malaysia began to implement polices to encourage renewable energy storage in 2011 with Feed-in Tariff [4,5,6,7,8,9,10,11]. In 2016, the scheme changed to NEM, which was modified in 2019. These polices are implemented with the aim of meeting the target for installing renewable energy in Malaysia. In achieving the aspirational goal of having 20% renewable energy in the country’s national installed capacity mix by 2025, the major renewable resource that will contribute to the RE mix is solar energy [12,13,14].

Three types of NEM have been implemented in recent years [14] i.e., NEM 2016 (NEM 1.0), NEM 2019 (NEM 2.0), and recently, NEM 2021 (NEM 3.0) [15,16,17]. In NEM 2016, Equation (1) is the total cost of the electricity bill generated monthly for the customer and is computed by deducting the price of the power generated by PV, which is MYR 0.31, from the price of the power consumed by the customer from the grid. The power generated by PV and the price of generated energy are computed using Equations (2) and (3), respectively.

$$\mathrm{Bill} \mathrm{price}= \mathrm{price} \mathrm{of} \mathrm{consumed} \mathrm{energy} - \mathrm{price} \mathrm{of} \mathrm{generated} \mathrm{energy}$$

(1)

$$\mathrm{Price} \mathrm{of} \mathrm{generated} \mathrm{energy} = \mathrm{power} \mathrm{generated} \mathrm{by} \mathrm{PV} \times \mathrm{displaced} \cos \mathrm{t} \mathrm{by} \mathrm{the} \mathrm{grid}$$

(2)

$$\mathrm{Price} \mathrm{of} \mathrm{consumed} \mathrm{energy} = \mathrm{power} \mathrm{consumed} \mathrm{by} \mathrm{the} \mathrm{customer} \times \mathrm{price} \mathrm{tariff}$$

(3)

However, in 2019, the NEM strategy changed, since not many customers installed PV systems based on the poor financial return from this policy. The policy now offsets the customer cost for every 1 kWh produced by the PV system with 1 kWh consumed from the grid. Equations (4) and (5) shows the monthly electricity bill computed after deducting the power generated by the customer from the power consumed:

$$\mathrm{Total} \mathrm{power} = \mathrm{power} \mathrm{consumed} \mathrm{from} \mathrm{grid} - \mathrm{power} \mathrm{generated} \mathrm{by} \mathrm{PV}$$

(4)

$$\mathrm{Electricity} \mathrm{bill} = \mathrm{total} \mathrm{power} \times \mathrm{price} \mathrm{tariff}.$$

(5)

Based on other case studies, this policy has a better financial return than NEM 2016 [10]. For commercial and industrial systems, the maximum capacity of the PV system installed is 1 MW or 75% of maximum demand (MD) of their existing installation, or 60% of the fuse rating of the transformer [12,13].

For domestic or residential consumers, the maximum capacity of the PV systems installed is less than or equal to 12 kW for a single phase or 72 kW for a three-phase system [11]. NEM 3.0 consists of three programs, each of which are assigned to a specific market sector. The first program is NEM Rakyat, which covers the residential segment [18,19]. A 100 MW capacity is allocated to this program, effective from 1 February 2021 [20]. The program applies the one-to-one NEM 3.0 policy for 10 years [21]. The allowed maximum PV installation capacity for the domestic consumer is 4 and 10 kW for single-phase and three-phase NEM consumers, respectively. The second program, called NEM GoMEn, covers government ministries and entities and has 100 MW allocated for solar power implementation. The program also applies a one-to-one offset for 10 years [22]. The maximum allowed PV installation capacity is 1000 kW per single account with a maximum of 75% from the MD, i.e., the average of the recorded MD of the past year or the declared MD for consumers with less than a one-year record. This is applicable for medium-voltage consumers and for low-voltage consumers not exceeding 60% of the fuse rating (for direct meters) or 60% of the current transformer (CT) rating of the metering current transformers, as shown in

Table 1. PV policies in Malaysia applied to commercial buildings.

Policy	Year	Definition	Notes	Ref.
FiT	2011–2016	The concept of FiTs is that the yield of the user-generated photovoltaic system is sold to the utility grid at a price set by the utility network. Two meters are installed; one is used to count the electricity consumed by the user, and the second meter measures the kWh produced by the PV system and sent to the grid.	It was the first policy implemented in Malaysia.	[6,7,8]
NEM 1.0	2016–2019	NEM enables customers to produce and use solar energy to satisfy demand. The extra PV electricity will be exported to the grid. This surplus power is subsequently offset by a rate of MYR 0.31/kWh from the next electricity bill.	The energy produced by the PV system is consumed by the owner and the excess energy is exported to the grid. There is not money offset—only a reduction in the next electricity bill.	[15,20,27,28]
NEM 2.0	2019–2021	This policy allows a consumer who produces photovoltaic energy to export the excess energy to the grid, and each kWh is compensated by another kWh from the next electricity bill.	Each one kWh exported to the grid will be offset from the next electricity bill by deducting the value of one kWh starting with the highest tariff. In the previous NEM, the energy exported to the grid would only be paid at a displaced cost of MYR 0.31/kWh.	[16,21,29]
NEM 3.0	2021–2023	Similar concept to NEM 2.0, apart from that it permits indirect connection to commercial buildings. The allowed installed capacity is 75% of MD for commercial buildings.	A hybrid system/indirect connection is allowed	[30]

[23].

Solar PV systems have many types based on different categories such as grid dependency. Some of the PV systems connect to the grid and use it as a battery storage alternative, and some systems are totally independent from the grid and use battery storage to store energy for nighttime use [16]. There are also hybrid systems using the grid as storage for excess PV energy or in case PV does not meet their demand, especially at night; at the same time, they use battery storage for a different reason [24,25]. This study focuses on the grid-connected PV system [26]. Most of the available studies focus on the technical advancement on the designed under the old used policies for small or large-scale PV systems in Malaysia. This paper provides detailed financial analysis for a rooftop commercial-sized PV system under the recent policy announced in 2021. The paper analysis proves the profitability of such projects under the recent policy and clarifies the limitation of a system implemented under NEM3.0.

1.3. Grid-Connected PV System

The primary component of grid-connected PV systems is the power conditioning unit (PCU). The PCU converts the DC power produced by the PV array into AC power as per the voltage and power quality requirements of the utility grid. A bidirectional interface is made between the PV system, AC output circuits, and the electric utility network; typically, an onsite distribution panel or service entrance [30,31,32] allows the AC power produced by the PV system to either supply onsite electrical loads or to back feed the grid when the PV system output is greater than the onsite load demand. This safety feature is required in all grid-connected solar PV [33].

One of the important components of an on-grid system is net metering. Standard service meters are odometer-type counting wheels that record power consumption at a service point by means of a rotating disc, which is connected to the counting mechanism. The rotating discs operate by an electro physical principle called the eddy current. Digital electric meters make use of digital electronic technology that registers power measurement by solid-state current and voltage sensing devices that convert analog measured values into binary values that are displayed on the meter using liquid crystal display (LCD) readouts [20]. Inverters are the main difference between a grid-connected system and a standalone system. The inverters must have the line frequency synchronization capability to deliver the excess power to the grid. Net meters have the capability to record consumed or generated power in an exclusive summation format. The recorded power registration is the net amount of power consumed—the total power used minus the amount of power that is produced by the solar power cogeneration system [34,35]. Net meters are supplied and installed by utility companies that provide grid-connection service systems [36]. Net metered solar PV power plants are subject to specific contractual agreements and are subsidized by state and municipal governmental agencies.

The usage profile (i.e., operation hours—24 h or not) of electricity is divided from Monday to Sunday into on-peak hours from 08:00 a.m. to 10:00 p.m. and off-peak hours from 10:00 p.m. to 08:00 a.m. Each period has a different tariff rate that is clarified in the next

Table 2. Site Information.

Type	Information
Location	Bangi, Selangor (Klang Valley)
Slope azimuth	180
Roof type	Clay and concrete tiles

. In order to understand the PV system’s financial benefit and policy rules, we must first identify the tariff that the user’s electricity falls under. After that, the policy suited to the user is selected.

1.4. Contribution and Paper Organization

New polices have been implemented over the last few years in Malaysia. This is to encourage the use of renewable energy and increase its share in the energy mix. The latest implemented policy is NEM 3.0, which allows 75% of an MD rooftop PV system to be connected to the utility grid. Due to the fact that this policy is newly implemented for this category of system size, not much analysis is available that gives detailed technical and financial information. This paper provides a case study that guides the user to size the system under the recent NEM 3.0 policy and achieve final profit saving. Section 2 discusses the methodology involved to achieve the final design. Section 3 defines the load consumption and system configuration. Section 4 explains the load profile of the selected case study with the adopted method in sizing the PV system. Finally in Section 5, the PVsyst tool provides a technical and financial analysis with some discussions, and a conclusion provided at the end of the paper.

2. Methodology

Traditionally, the PV system size is obtained through the electricity profile of the consumer where the final design cost of the kWh produced using the PV system must be less than the price of the grid tariff. The PV system size must be adjusted by calculating the sun peak hours in the specific location and the average electricity used daily for a year of consumption, plus the available roof space to install the PV system; thus, the PV system size is computed. However, based on the recent NEM 3.0 policy in Malaysia, only 75% of MD is allowed to be installed and connected to the grid [37,38].

The components of the PV system are selected through the power rating decided by the manufacturers for the appliances, in conjunction with a careful estimation of how long each appliance will need power [39]. However, this can apply for small PV installation. In a large PV plant, the electricity demand based on the previous year of the electricity profile is thoroughly studied.

The PVsyst tool is commercially available software that is used to simulate solar PV projects. This study used a PV system for modeling purposes. The PVsyst software library contains detailed data about the most common photovoltaic modules, inverters, and all that is needed for a photovoltaic system project. Furthermore, it records losses due to the partial shadowing effects, mismatches between connected PV modules, wiring losses, inverter losses, and the effect of the ambient temperature variations on its electrical output power calculation. This functionality makes it a precise tool to estimate the amount of electrical energy produced by a designed system [40,41].

3. System Configuration

The grid-connected PV system configuration is simple compared with the off-grid PV system, which requires battery storage. It contains PV solar plants, an inverter, a meter, wiring, and a mounting system, as shown in Figure 1. The solar PV plant converts the photons in the sunlight into electricity that runs as DC [26,27]. The electricity enters the inverter, and then, it is transformed into AC to suit the appliances of the building [28]. The extra electricity is exported to the utility grid where it is measured by a meter. The meter also measures the electricity imported from the utility grid.

The site selected in this case study is denoted as building A, which is described in Table 2. The building is located in the Bangi area in Selangor, Malaysia and has a lot of empty spaces on the roof without any shading from nearby buildings or trees. The roof was sturdy and made of clay and concrete tiles, which make it possible to install a PV system that the roof will bear its weight.

4. Load Profile

In order to implement the NEM on the commercial building, load profile information was collected and analyzed. The collected data determined the size of the solar PV system. At present, the customer is using 100% electricity from the utility grid. From

Table 3. Customer electricity profile for the year 2019.

Month	Demand, kWh	MD, kW	MD, MYR	Cost, MYR
JAN	141,265	95	4285	47,957
FEB	127,680	552	24,895	43,727
MAR	346,075	95	4285	129,553
APRIL	100,093	502	22,640	100,094
MAY	357,702	494	22,279	108,422
JUN	283,652	499	22,505	113,256
JULY	344,294	514	23,181	133,032
AUG	342,547	503	22,685	342,158
SEP	299,892	502	22,640	118,990
OCT	331,863	491	22,144	128,770
NOV	335,701	498	22,460	130,132
DEC	283,513	496	22,370	113,350
TOTAL	3,194,184	-	-	1,509,441
Average	274,523	505 *	19,697	125,787

* exclude of Jan and March.

, it can be seen that the total yearly energy consumption was 3,194,184 kWh with an average monthly cost of MYR 125,787. It can be noticed that JAN and MAR are much lower than the other peak hours in other months due to system measurement dysfunction. These two months were excluded when computing the average peak hour.

5. System Sizing

The system size was designed based on the customer’s electrical profile during the year 2019. The peak sun hours of 2019 were 4.4 h on average based on Table 1. The total yearly electrical consumption was 3,194,184 kWh. The building falls under the ‘C Tariff’ with an electricity price during peak hours of MYR 0.365/kWh, an off-peak price of MYR 0.224/kWh, and an MD of MYR 45/kW.

In order to calculate the system size, we obtained the MD point of every month of in 2019 and calculated the average point, which was 505 kW.

Size of PV system = MD × 75% = 505 kW × 75% = 378.75 kW ≅ 380 kW

(6)

The allowed PV system size to connect to the utility grid is 380 kW, which is 16% of the total electricity demand. The annual global solar irradiation of the location of the Building A was measured using the PVsyst program, producing a value of 4.4144 kWh/m². The average ambient temperature was 27.4 °C.

Table 4. Monthly global solar irradiation and the output of a 1 kW PV system.

Month	AC System Output (kWh)	Solar Radiation (kWh/m2/day)	Irradiance (W/m2)	DC Array Output (kWh)
1	103.19	4.44	137.60	107.85
2	95.95	4.55	127.47	100.29
3	104.86	4.52	140.15	109.62
4	94.78	4.19	125.55	99.10
5	89.40	3.80	117.80	93.58
6	85.31	3.77	113.08	89.36
7	89.52	3.80	117.91	93.78
8	94.33	4.01	124.28	98.72
9	95.52	4.21	126.16	99.85
10	98.78	4.21	130.44	103.25
11	95.13	4.20	125.87	99.45
12	95.95	4.05	125.55	100.34
Total	1142.72	49.74	1511.86	1195.19

shows the monthly global solar irradiation and the output of a one kW PV system at that location.

After sizing the system according to 75% MD, the PV system production could only cover 380 kW of electricity demand. While this is seen lower compared to the 2671.2 kW PV plant where electricity demand was met 100%, this still could reduce the electricity bill and cost saving, particularly since the MD for electricity is recorded during the peak hours.

6. PV System Analysis Using PVsyst Tools

PVsyst is a design tool that provides optimization tools for sizing grid-connected, standalone, and pumping PV systems based on the location on the map. The tool also depends on the consumer electricity profile and the demands of electricity. It also provides a financial visibility for the designed project with environmental impact measured in tonnes. The program contains the latest used technology in the market, which can be selected during the sizing process. It can also calculate the loss in the system [23]. On the other hand, there are many other online program tools that help calculate the system size based on the location and demand of the user such as HOMER and PVWATT. However, PVsyst is chosen in this work for its flexibility when choosing the modules used as well as more specification details as opposed to PVWATT. The annual energy yield for the proposed PV power plant was defined as the amount of energy fed into the grid after due consideration of all kinds of generation and distribution losses. The solar PV-based power plant comprises the optical energy input (which is essentially dependent on the geographical/seasonal/climatic and operating parameters with time) and the electrical output (which depends on the technical specifications of the electrical appliances in use). Industry standard software PVsyst V6.8.1 was used for the Energy Generation Assessment.

The system consisted of 810 units of 470 Wp PV modules that connected in 81 strings with 10 modules in each string connected in series. The total nominal power of the plant was 380 kWp, as shown in

Table 5. PV module details.

Parameters	Values
PV module size	470 Wp
Number of modules	810 units
Nominal (STC)	380 kWp
Modules	81 strings × 10 in series
Pmpp	707 V
Umpp	501 A
Module area	1751 m2

.

The inverter used for this system design was a 100 kWac power inverter. Three inverters were used for the whole system. The inverters’ operating system was 630–1000 V and the DC to AC power conversion ratio was 1.27, as shown in

Table 6. Installed inverter details.

Parameters	Values
Unit Nom Power	100 kWac
Number of inverters	3 units
Total power	380 kWac
Operating voltage	630–1000 V
Pnom ratio (DC:AC)	1.27

.

The proposed 380 kW solar PV plant is expected to generate about 510 MWh of energy in the first year of operation at a net Capacity Utilization Factor (CUF) of 18% at the metering point, as per

Table 7. Balance and main results.

	GlobHor kWh/m2	DiffHor kWh/m2	T_Amb °C	Globlnc kWh/m2	GlobEff kWh/m2	EArray MWh	E_Grid MWh	E_Grid MWh
JAN	133.6	79.58	27.21	140.4	137.0	44.38	43.10	0.806
FEB	131.6	81.85	27.84	135.4	132.0	42.72	41.55	0.806
MAR	153.8	88.56	28.27	153.6	149.9	48.24	46.89	0.802
APR	142.7	73.33	27.86	138.6	135.0	43.44	42.15	0.799
MAY	144.8	77.78	28.71	136.7	132.5	42.88	41.59	0.799
JUN	133.0	70.24	28.20	124.4	120.7	39.19	37.98	0.802
JUL	134.4	81.91	28.20	126.7	122.7	39.98	38.77	0.804
AUG	136.7	82.95	28.09	131.4	127.7	41.52	40.27	0.805
SEP	133.6	69,76	27.38	132.1	128.8	41.45	40.20	0.799
OCT	140.5	86.62	27.67	143.0	139.6	45.20	43.88	0.806
NOV	124.6	69.35	26.85	130.2	127.4	41.12	39.87	0.804
DEC	121.3	67.82	27.27	128.1	125.0	40.37	39.13	0.802
YEAR	1630.5	929.75	27.80	1620.5	1578.1	510.49	495.39	0.803

. Thereafter, an annual degradation factor of 2.5% for the first year and 0.7% thereafter in production has been considered for mono crystalline modules for financial calculations.

The CUF—Capacity Utilization Factor compares 380 kW solar power plants with other 380 kW power plants that run 24 × 7 for 365 days in terms of how much energy is generated. If the 380 kW solar power plant generates 100 s of Wh for 365 days running on 24 × 7 and we have some 50 s of Wh at the end of our solar plant, its capacity utilization would be 50%. The average ratio is 0.803. The PV system’s nominal power output is 380 kW. Due to various factors such as site location and system losses, the power capacity of the system was reduced, as shown in Figure 2. The energy yield was calculated based on the south-facing array surface. The expected plant production for different probability scenarios (the probability of meeting a generation value) is also presented in Figure 2.

The yield factor was defined to be a factor consolidating all the system losses that occurred across this power plant. The major losses that occurred during the operation of the solar PV power plant were temperature loss, module mismatch loss, and DC to AC conversion losses. Figure 3 presents the loss diagram over the whole year. The diagram represents the energy flows in the system and the losses from every parts. Figure 3 shows that the largest losses came from temperature with 7.77%, while the inverter loss was 1.47%, which is expected from the manufacturing datils of the components.

7. Financial Analysis

The objective of financial analysis is to assess the financial viability of the project from the perspective of a project developer so as to arrive at a suitable investment decision. As shown in

Table 8. Cost details of the PV system components.

Item	Quantity Units	Cost, MYR	Total, MYR
PV modules	810	932	755,121
Inverter	3	80,332	240,996
Other components	1	289,195	289,195
Installation	810	238	192,797
Operating cost		5141	5141
Total			1,478,109

, all of the costing is in Malaysian Ringgit (MYR). The system cost included the cost of the PV modules, inverters, mounting materials, other components (cables, mounting system, charge controller and utility meter, etc.), the balance of the system, and interconnection [29].

Based on Table 8, the total installation cost is MYR 1,478,108.8; the operating cost is MYR 5141.25/year produced energy, and the cost of the produced energy (LCOE) is MYR 0.130/kWh. After a detailed analysis, it was concluded that the project is financially viable and that it will have a project lifetime of 25 years (starting year 2022), financing cost at MYR 1,478,108.8, and a payback period of 8.4 years. The net present value (NPV) is MYR 2,459,445.1, and the return on investment (ROI) would be 166.4%, as shown in Figure 4. Due to the degradation of the PV system, the profit starts to decrease in the last years of the project lifetime.

From Figure 5, it can be observed that from the ninth year, the project will be in the positive y-axis, beginning to generate profit from the initial investment. Cash flow was calculated based on (1) the tariff rate for each unit (kWh) by the solar plant against (2) the fixed cost of the investment and (3) the operational cost annually. By calculating the difference as = (1) − (2 + 3), we derived the amount shown in the graph. All the costs were equalized for a lifespan of 25 years. For the first 8.4 years, the investment cost is greater than the profit amount; then, the breakeven point is reached, and positive values result in annual profits from the PV system.

8. Environmental Impact

The implementation of solar power has been greatly encouraged due to its influence on reducing carbon emissions. Thus, it is important to measure the environmental benefit of using solar energy instead of fossil fuel. Figure 6 shows the amount of CO₂ emission saved during the lifetime of the project. The calculations depend majorly on the value of the life cycle emissions (LCA), which represent CO₂ emissions associated with a given component or quantity of energy. This includes the total life cycle of a component or the amount of energy, including production, operation, maintenance, disposal, etc. The rationale behind the carbon footprint tool is that the electricity generated by the photovoltaic system will replace the same amount of electricity in the existing grid. If the carbon footprint of the electricity generation on the grid is more than the PV system per kWh, carbon dioxide emissions will be reduced. From Figure 6, CO₂ emission is negative until the last 10 years of the project; then, it becomes positive due to the fact that the PV system installed satisfies only 16% of the consumer demand. The rest of the demand is met by the grid of utilities using traditional fossil fuel energy that causes CO₂ emissions in the air.

9. Discussion

The average annual solar radiation at the proposed site on the horizontal surface is about 1598 kWh/m² (as per NASA-SSE satellite data) [42], which is adequate for the installation of the solar PV ground-mounted utility scale system. Annual expected generation for the entire solar PV project is 510 MWh/year, where the evaluation is based on a probabilistic approach for the interpretation of the simulation results over several years.

The 380 kW grid-connected PV system consists of 810 PV solar modules grouped into 20 × 81 strings with each string containing 10 modules in series. The output of the strings is pooled in the array junction box through 4 mm² photovoltaic DC cables. The output from the junction box is fed to the three grid-tied inverters. The grid-connected inverter is used as a power conditioning unit. DC and AC distribution cabinets contain protective components for the safety of the system.

Based on the results obtained in PVsyst tools, one day of energy production by the PV system plant was measured and compared with the total electricity demand in one day, as shown in Figure 2. From the figure, it can be seen that only 16% of the electricity demand is covered. This is due to the restricted rule of NEM that only allows 75% of the MD of electricity to be connected to the utility grid.

Although the PV system plant would only cover 16% of the total electricity demand, the reduction in the electricity bill would be significant since the solar PV plant produces energy during the on-peak hours. The electricity rates are MYR 0.365/kWh and MYR 0.224/kWh during on-peak and off-peak hours, respectively. Moreover, the MD point during the day can also be covered by the PV plant or can be reduced significantly. Since this plant is small compared with the electricity demand of the building, it will not export electricity except for on the weekends. It is expected that the electricity will be used on a daily basis, as shown in Figure 7.

10. Conclusions

A techno-economic analysis of commercial-size grid-connected rooftop solar PV systems has been presented in this paper, taking into account the recently announced NEM 3.0 scheme in 2021. The availability of the solar irradiance at that location is relatively high i.e., 4.4144 kWh/m² day throughout the year. The size of the PV plant was calculated based on the consumer electricity profile of one year. The average MD of 505 kW was considered for sizing 75% of the system. Due to the fact that the power output of the PV system is 510 MWh/year, the PV system size would only cover 16% of the yearly electricity demand. After sizing the PV system, it was modeled and simulated using the PVsyst program. The system performance showed promising results of 510.49 MWh produced yearly from the plant. A financial analysis was carried out with an estimation of the system price based on percentage and rates from the original country of the building location. Based on the analysis, the project’s ROI is in 8.4 years, and the LCOE is at MYR 0.130/kWh, which is less than both tariffs from the utility during on-peak and off-peak hours. The net present value (NPV) is MYR 2,459,445.1, and ROI is positive and equal to 166.4%. The system would have a positive environmental impact with a reduction in the emission of CO₂ at least until the end of the tenure agreement. The results from this project analysis show good promise and benefits not just for energy and cost savings but also in terms of utilizing the dead spaces on the rooftop of buildings.