Common use of Calculation of the PV System Equivalent Availability Factor Clause in Contracts

Calculation of the PV System Equivalent Availability Factor. Following the end of each LD Period, the PV System Equivalent Availability Factor shall be calculated for such LD Period as follows: PV System Equivalent Availability Factor = where: Period Hours (PH) is the total number of hours in the LD Period counting twenty-four (24) hours per day minus ExcludedTime. In a normal year, PH = 8,760 minus ExcludedTime, and in a leap year PH = 8,784 minus ExcludedTime. Available Hours (AH) is the number of hours that the PV System is not on Outage. It is the sum of all Service Hours (SH) + Reserve Shutdown Hours (RSH). An "Outage" exists whenever the entire PV System is not online producing electric energy and is not in a Reserve Shutdown state, resulting from Seller-Attributable Non-Generation but excluding ExcludedTime. Service Hours (SH) is the number of hours during the LD Period the PV System is online and producing electric energy to meet Company Dispatch and/or to maintain the XXXX State of Charge. Reserve Shutdown Hours (RSH) is the number of hours the PV System was available to the Company System but not providing electric energy or is offline for reasons other than Seller-Attributable Non-Generation, or is offline due to insufficient irradiance levels based on the inverter manufacturer's minimum irradiance level for production. All hours except for ExcludedTime between 7:00 pm and 6:00 am will be considered RSH. The PV System will be considered RSH in these hours, even if the system would otherwise be in an outage or derated state. A "Deration" exists if the Facility is available for Company Dispatch, but at less than full potential output for the given irradiance conditions. Derations include only periods of Seller-Attributable Non-Generation and derations by Company pursuant to Section 8.3 (Company Rights of Dispatch). Derations do not include periods of ExcludedTime. Each individual Deration is transformed into equivalent full outage hour(s). For Derations due to inverter outages, this is calculated by multiplying the actual duration of the derating (hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. For Derations by Company pursuant to Section 8.3 (Company Rights of Dispatch), this is calculated by the size of the Deration (in MW) divided by the Contract Capacity. For avoidance of doubt, if the Facility is in an Outage it cannot also be in a Deration. Equivalent Planned Derated Hours (EPDH) includes Planned Derations (PD) and Maintenance Derations (D4). A Planned Deration is when the PV System experiences a Deration scheduled well in advance and for a predetermined duration. A Maintenance Deration is a Deration that can be deferred beyond the end of the next weekend (Sunday at midnight or before Sunday turns into Monday) but requires a reduction in capacity before the next Planned Deration (PD). Each individual Deration is transformed into equivalent full outage hour(s). Equivalent Unplanned Derated Hours (EUDH): An Unplanned Deration (Forced Deration) occurs when the PV System experiences a Deration that requires a reduction in availability before the end of the nearest following weekend. Unplanned Derations include those due to Seller-Attributable Non-Generation. Each individual Unplanned Deration is transformed into equivalent full outage hour(s). For Derations due to inverter outages, this is calculated by multiplying the actual duration of the Deration (in hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. For Derations by Company pursuant to Section 8.3 (Company Rights of Dispatch) this is calculated by the size of the deration (in MW) divided by the Contract Capacity. These equivalent hour(s) are then summed. ExcludedTime is unavailability as a result of the PV System or a portion of the PV System being unavailable due to Force Majeure. The hours and/or equivalent hours of ExcludedTime shall not be added to Available Hours and shall be subtracted from Period Hours. This is calculated by multiplying the actual duration of the event that counts as ExcludedTime (in hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. These equivalent hour(s) are then summed. The effect of Force Majeure is taken into account in calculating the PV System Equivalent Availability Factor over the 12 calendar month LD Period as follows: When an LD Period contains a month during which the PV System or a portion of the PV System is unavailable due to Force Majeure, then such month shall be excluded from the LD Period and the LD Period shall be extended back in time to include the next previous month during which there was no such unavailability of the PV System or a portion thereof due to Force Majeure.

Calculation of the PV System Equivalent Availability Factor. Following the end of each LD Period, the PV System Equivalent Availability Factor shall be calculated for such LD Period as follows: PV System Equivalent Availability Factor = where: Period Hours (PH) is the total number of hours in the LD Period counting twenty-four (24) hours per day minus ExcludedTimeday. In a normal year, PH = 8,760 minus ExcludedTime8,760, and in a leap year PH = 8,784 minus ExcludedTime8,784. Available Hours (AH) is the number of hours that the PV System is not on Outage. It is the sum of all Service Hours (SH) + Reserve Shutdown Hours (RSH). An "Outage" exists whenever the entire PV System is not online producing electric energy and is not in a Reserve Shutdown state, resulting from SellerSubscriber Organization-Attributable Non-Generation but excluding ExcludedTimeGeneration. Service Hours (SH) is the number of hours during the LD Period the PV System is online and producing electric energy to meet Company Dispatch and/or to maintain the XXXX State of Charge. Reserve Shutdown Hours (RSH) is the number of hours the PV System was available to the Company System but not providing electric energy or is offline for reasons other than SellerSubscriber Organization-Attributable Non-Generation, or is offline due to insufficient irradiance levels based on the inverter manufacturer's minimum irradiance level for production. All hours except for ExcludedTime between 7:00 pm and 6:00 am will be considered RSH. The PV System will be considered RSH in these hours, even if the system would otherwise be in an outage or derated state. A "Deration" exists if the Facility is available for Company Dispatch, but at less than full potential output for the given irradiance conditions. Derations include only periods of SellerSubscriber Organization-Attributable Non-Generation and derations by Company pursuant to Section 8.3 (Company Rights of Dispatch). Derations do not include periods of ExcludedTime. Each individual Deration is transformed into equivalent full outage hour(s). For Derations due to inverter outages, this is calculated by multiplying the actual duration of the derating (hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. For Derations by Company pursuant to Section 8.3 (Company Rights of Dispatch), this is calculated by the size of the Deration (in MW) divided by the Contract Capacity. For avoidance of doubt, if the Facility is in an Outage it cannot also be in a Deration. Equivalent Planned Derated Hours (EPDH) includes Planned Derations (PD) and Maintenance Derations (D4). A Planned Deration is when the PV System experiences a Deration scheduled well in advance and for a predetermined duration. A Maintenance Deration is a Deration that can be deferred beyond the end of the next weekend (Sunday at midnight or before Sunday turns into Monday) but requires a reduction in capacity before the next Planned Deration (PD). Each individual Deration is transformed into equivalent full outage hour(s). These equivalent hour(s) are then summed. Equivalent Unplanned Derated Hours (EUDH): An Unplanned Deration (Forced Deration) occurs when the PV System experiences a Deration that requires a reduction in availability before the end of the nearest following weekend. Unplanned Derations include those due to SellerSubscriber Organization-Attributable Non-Generation. Each individual Unplanned Deration is transformed into equivalent full outage hour(s). For Derations due to inverter outages, this is calculated by multiplying the actual duration of the Deration (in hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. For Derations by Company pursuant to Section 8.3 (Company Rights of Dispatch) this is calculated by the size of the deration (in MW) divided by the Contract Capacity. These equivalent hour(s) are then summed. ExcludedTime is unavailability as a result of the PV System or a portion of the PV System being unavailable due to Force Majeure. The hours and/or equivalent hours of ExcludedTime shall not be added to Available Hours and shall be subtracted from Period Hours. This is calculated by multiplying the actual duration of the event that counts as ExcludedTime (in hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. These equivalent hour(s) are then summed. The effect of Force Majeure is taken into account in calculating the PV System Equivalent Availability Factor over the 12 calendar month LD Period as follows: When an LD Period contains any hours in a month during which the PV System or a portion of the PV System is unavailable due to Force Majeure, then such month shall be excluded from the LD Period and the LD Period shall be extended back in time to include the next previous month during which there was no such unavailability of the PV System or a portion thereof due to Force Majeure. This means the PV System Equivalent Availability Factor would not change from that determined in the month directly preceding a month containing Forced Majeure.

Calculation of the PV System Equivalent Availability Factor. Following the end of each LD Period, the PV System Equivalent Availability Factor shall be calculated for such LD Period as follows: PV System Equivalent Availability Factor = where: Period Hours (PH) is the total number of hours in the LD Period counting twenty-four (24) hours per day minus ExcludedTimeday. In a normal year, PH = 8,760 minus ExcludedTime8,760, and in a leap year PH = 8,784 minus ExcludedTime8,784. Available Hours (AH) is the number of hours that the PV System is not on Outage. It is the sum of all Service Hours (SH) + Reserve Shutdown Hours (RSH). An "Outage" exists whenever the entire PV System is not online producing electric energy and is not in a Reserve Shutdown state, resulting from Seller-Attributable Non-Generation but excluding ExcludedTimeGeneration. Service Hours (SH) is the number of hours during the LD Period the PV System is online and producing electric energy to meet Company Dispatch and/or to maintain the XXXX State of Charge. Reserve Shutdown Hours (RSH) is the number of hours the PV System was available to the Company System but not providing electric energy or is offline for reasons other than Seller-Attributable Non-Generation, or is offline due to insufficient irradiance levels based on the inverter manufacturer's minimum irradiance level for production. All hours except for ExcludedTime between 7:00 pm and 6:00 am will be considered RSH. The PV System will be considered RSH in these hours, even if the system would otherwise be in an outage or derated state. A "Deration" exists if the Facility is available for Company Dispatch, but at less than full potential output for the given irradiance conditions. Derations include only periods of Seller-Attributable Non-Generation and derations by Company pursuant to Section 8.3 (Company Rights of Dispatch). Derations do not include periods of ExcludedTime. Each individual Deration is transformed into equivalent full outage hour(s). For Derations due to inverter outages, this is calculated by multiplying the actual duration of the derating (hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. For Derations by Company pursuant to Section 8.3 (Company Rights of Dispatch), this is calculated by the size of the Deration (in MW) divided by the Contract Capacity. For avoidance of doubt, if the Facility is in an Outage it cannot also be in a Deration. Equivalent Planned Derated Hours (EPDH) includes Planned Derations (PD) and Maintenance Derations (D4). A Planned Deration is when the PV System experiences a Deration scheduled well in advance and for a predetermined duration. A Maintenance Deration is a Deration that can be deferred beyond the end of the next weekend (Sunday at midnight or before Sunday turns into Monday) but requires a reduction in capacity before the next Planned Deration (PD). Each individual Deration is transformed into equivalent full outage hour(s). These equivalent hour(s) are then summed. Equivalent Unplanned Derated Hours (EUDH): An Unplanned Deration (Forced Deration) occurs when the PV System experiences a Deration that requires a reduction in availability before the end of the nearest following weekend. Unplanned Derations include those due to Seller-Attributable Non-Generation. Each individual Unplanned Deration is transformed into equivalent full outage hour(s). For Derations due to inverter outages, this is calculated by multiplying the actual duration of the Deration (in hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. For Derations by Company pursuant to Section 8.3 (Company Rights of Dispatch) this is calculated by the size of the deration (in MW) divided by the Contract Capacity. These equivalent hour(s) are then summed. ExcludedTime is unavailability as a result of the PV System or a portion of the PV System being unavailable due to Force Majeure. The hours and/or equivalent hours of ExcludedTime shall not be added to Available Hours and shall be subtracted from Period Hours. This is calculated by multiplying the actual duration of the event that counts as ExcludedTime (in hours) by the number of inverters in the PV System offline and dividing by the total number of inverters in the PV System. These equivalent hour(s) are then summed. The effect of Force Majeure is taken into account in calculating the PV System Equivalent Availability Factor over the 12 calendar month LD Period as follows: When an LD Period contains any hours in a month during which the PV System or a portion of the PV System is unavailable due to Force Majeure, then such month shall be excluded from the LD Period and the LD Period shall be extended back in time to include the next previous month during which there was no such unavailability of the PV System or a portion thereof due to Force Majeure.. This means the PV System Equivalent Availability Factor would not change from that determined in the month directly preceding a month containing a Force Majeure. EXAMPLE: The following is an example of a PV System Equivalent Availability Factor calculation and is included for illustrative purposes only. Assume the following: