Common use of Certain Specifications for the Facility Clause in Contracts

Certain Specifications for the Facility. (i) Seller shall furnish, install, operate and maintain the Facility including breakers, relays, switches, synchronizing equipment, monitoring equipment and control and protective devices approved by Company as suitable for parallel operation of the Facility with Company System in accordance with the terms of the PPA and this Agreement. The Facility shall be accessible at all times to authorized Company personnel. (ii) The Facility shall include: (a) The Fuel processing, biomass boiler and electrical equipment as described in Attachment D of the Power Purchase Agreement. (b) 13.8 kV circuit breaker capable of three (3) cycle clearing and equipped with MRCTs as shown on Schedule 1 with 2000:5 ratio and C400 accuracy class or higher. (c) 13.8kV/69kV Step up transformer, 20/27/33MVA OA/OA/FA rating, Wye-grounded high voltage to Delta low voltage connected windings, with adequate high voltage taps to allow generator to export power at a power factor range indicated in Article 2. Transformer shall have one set of 600/5 multi-ratio current transformers with accuracy C800 for the ground neutral overcurrent relay protection (Device 50/51N); step-up transformer equipped with high voltage and low voltage lightning arresters mounted on brackets close to the transformer terminals. (d) Lightning arresters mounted on the 69KV deadline line structure or metering structure (3) rated at 54kV. (e) Dial-up telephone line installed close to 69 kV metering cabinet to allow remote metering reading by Company. Seller will be responsible for the installation and maintenance cost of the telephone line. This telephone line may be shared with other existing telephone lines (f) 69 kV manual disconnect at step-up transformer enclosure (g) 69 kV metering devices (Primary & Backup) connected to one set of 69kV potential transformers (“PTs”) and 69kV current transformers (“CTs”) to monitor the Facility step-up transformer. All instrument transformers with dry type and metering class accuracy. Included, but not limited to, potential fuse safety switches, current test-switches, meter cabinet and Form 9S meter sockets to enable sharing the instrument transformers for the primary and backup meters. Undervoltage relay to monitor and provide alarm back to the Company’s EMS for loss of metering potential. Two meters will be provided by the Company. (a) Seller to provide documentation on dry type metering PTs and dry type CTs to verify metering class construction and accuracy. (h) 25 kV class cable with normal insulation or 15 kV class cable with 100% insulation required for reliable generator operation on the delta configured side of the step-up transformer. Additional insulation required to withstand the rise in potential on the un-faulted phases during a single-line to ground fault. Install associated ductline and handhold from Seller’s step-up transformer to Seller’s plant switchgear. (i) Communication system including fiber cable and communication equipment to interface to Seller’s Control System to allow Company to remotely monitor and control the load and power factor of the Facility. Seller’s Control System shall include, but not be limited to, a demarcation cabinet, ancillary equipment and software necessary for Seller to connect to Company’s Remote Terminal Unit (“RTU”), which shall provide the control signals to Facility and send feedback status and analogs to Company’s EMS including, at a minimum, the following outputs: net generating facility separate MW and Mvar transducers (measured at the Point of Interconnection), separate generator ▇▇▇▇▇ ▇▇ and Mvar transducers, upper MW limit for remote dispatch control (equal to Available Capacity), low MW limit for remote dispatch control, ramp rate under remote dispatch control, Mvar high and low limit based on unit capability curve at present MW, enable/disable status for remote dispatch control, meter loss of potential alarm, Seller’s 13.8 kV breaker open/close status, and other control functions that need to be interfaced with the RTU (MW raise/lower input from Company EMS, Voltage Target Setpoint Raise/Lower from Company EMS). The separate MW and Mvar transducers with 0-1 ma output and a +/- 0.1% accuracy signal to the Company’s supervisory system. (j) A power source to Seller’s Control System that is immune to system transients which may be the plant battery, a separate Uninterruptible Power Supply, or equivalent. (k) Protective relays at Seller's Facility per Attachment A, Schedule 1 (New Switchyard Single-Line Drawing (4/13/12)) and Attachment A, Schedule 2 ( New Switchyard Relay List And Trip Scheme (4/11/12)). In the event of any conflict between the specifications, the aforesaid Attachment A, Schedule 1 and Attachment A, Schedule 2 shall control. All relay settings to shall be stamped by Seller's State of Hawaii licensed electrical engineer. Relay setting to be implemented by Seller's licensed electrical contractor and verified by Company. The relays are: (1) Step up transformer differential relay to detect electrical faults within the step up transformer (SEL-387E) which will trip the 69 kV breakers in the Switchyard and the 13.8 kV breaker in Seller's Facility. (2) Step up transformer neutral ground overcurrent relay (device 350N/351N) and transformer sudden pressure relay (device 63) to detect faults within the step up transformer and trip the 69 kV breakers in the Switchyard and the 13.8 kV breaker in Seller's Facility. (3) Phase overcurrent relays (3) on the low voltage side of the step-up transformer (device 350/351) to trip the 13.8 kV circuit breaker for faults below the low voltage bushing. (4) Breaker failure relaying as shown on Schedule 1 and 2. These devices are SEL-501 breaker failure relays or equivalent. (l) Seller's generating facility switchgear and protective relays including phase overvoltage (device 59), undervoltage (device 27), voltage unbalance (device 47), reverse phase or phase unbalance (device 46), automatic lockout (device 86) set at "no restart mode", anti- motoring (device 32M), and over/under frequency (devices 810 & 81D). Relay settings to be prepared and stamped by Seller's State of Hawaii licensed electrical engineer. Relay settings to be implemented by Seller's contractors. (m) Tie breaker status and generator breaker status signals to Company supervisory control system. (iii) The Facility will comply with the recommendations of the updated February 2012 Interconnection Requirements Study and the following:

Certain Specifications for the Facility. (i) i. Seller shall furnish, install, operate and maintain the Facility including breakers, relays, switches, synchronizing equipment, monitoring equipment and control and protective devices approved by Company as suitable for parallel operation of the Facility with the Company System in accordance with the terms of the PPA and this AgreementSystem. The Facility shall be accessible at all times to authorized Company personnel. (ii) . The Facility shall include: • Generation turbines, generators, fly-wheels (if required), vaporizers, pre-heaters, Air-coolers, Feed-pumps, Electrical power shelters or Electrical room, and Motive fluid tank. • 13.8 kV circuit breakers • Step up transformers • Lightning arresters • 69 kV circuit breakers • 69 kV metering devices(Primary & Backup) connected to one metering set of instrument transformers per transformer, to monitor each of three (3) step-up transformers • Dial-up telephone line for remote metering • Demarcation cabinet • Underground cable and ductline from the Seller switching station to the Seller’s Facility • Interconnection relays and relay settings • Generation relays and generation relay settings • 13.8 kV bus as shown in Attachment E • 13.8 kV breaker status and generator breaker status signals to the Company supervisory control system A description of the Seller’s Facility follows: (a1) Generation resources consist of four (4) OECs (Ormat Energy Converter) units which are designed to utilize the energy of geothermal steam or brine. Each OEC unit includes a synchronous generator that is driven by an organic turbine, air-cooled condenser, cycle pump and control system. The Fuel processing, biomass boiler gathering system conveys steam and electrical equipment as described in Attachment D brine from the existing separator to the Facility. The steam and brine pass through the Facility OEC units and flow through the gathering system to the re-injection system which collects a mixture of the Power Purchase Agreementcooled brine and condensate that passed through the Facility and re-injects it into re-injection ▇▇▇▇▇ by the Facility’s re-injection pumps. (b2) 13.8 15 kV circuit breaker capable of three five (35) cycle clearing and equipped with MRCTs multi ratio current transformers (MRCTs) as shown on Schedule 1 in Attachment E with 2000:5 ratio and C400 C200 accuracy class or higher. class. (c3) 13.8kV/69kV Three (3) Step up transformertransformers, 20/27/33MVA 16/22/31.25 MVA OA/OA/FA rating, Wye-grounded high voltage to Delta low voltage connected windings, with adequate high voltage taps to allow generator to export power at a power factor range indicated in Article 2. Section 3(c) (Reactive Power Characteristics) of this Attachment B (Facility Owned by Seller)A. Transformer shall have one set of 600/5 has phase and neutral multi-ratio current transformers with accuracy C800 for the ground neutral overcurrent relay protection as indicated in Section 3(c) (Device 50/51N); step-up transformer equipped with high voltage and low voltage lightning arresters mounted on brackets close to the transformer terminals. Reactive Power Characteristics) of this Attachment B (d) Lightning arresters mounted on the 69KV deadline line structure or metering structure (3) rated at 54kV. (e) Dial-up telephone line installed close to 69 kV metering cabinet to allow remote metering reading by Company. Seller will be responsible for the installation and maintenance cost of the telephone line. This telephone line may be shared with other existing telephone lines (f) 69 kV manual disconnect at step-up transformer enclosure (g) 69 kV metering devices (Primary & Backup) connected to one set of 69kV potential transformers (“PTs”) and 69kV current transformers (“CTs”) to monitor the Facility step-up transformer. All instrument transformers with dry type and metering class accuracy. Included, but not limited to, potential fuse safety switches, current test-switches, meter cabinet and Form 9S meter sockets to enable sharing the instrument transformers for the primary and backup meters. Undervoltage relay to monitor and provide alarm back to the Company’s EMS for loss of metering potential. Two meters will be provided by the Company. (a) Seller to provide documentation on dry type metering PTs and dry type CTs to verify metering class construction and accuracy. (h) 25 kV class cable with normal insulation or 15 kV class cable with 100% insulation required for reliable generator operation on the delta configured side of the step-up transformer. Additional insulation required to withstand the rise in potential on the un-faulted phases during a single-line to ground fault. Install associated ductline and handhold from Seller’s step-up transformer to Seller’s plant switchgear. (i) Communication system including fiber cable and communication equipment to interface to Seller’s Control System to allow Company to remotely monitor and control the load and power factor of the Facility. Seller’s Control System shall include, but not be limited to, a demarcation cabinet, ancillary equipment and software necessary for Seller to connect to Company’s Remote Terminal Unit (“RTU”), which shall provide the control signals to Facility and send feedback status and analogs to Company’s EMS including, at a minimum, the following outputs: net generating facility separate MW and Mvar transducers (measured at the Point of Interconnection), separate generator ▇▇▇▇▇ ▇▇ and Mvar transducers, upper MW limit for remote dispatch control (equal to Available Capacity), low MW limit for remote dispatch control, ramp rate under remote dispatch control, Mvar high and low limit based on unit capability curve at present MW, enable/disable status for remote dispatch control, meter loss of potential alarm, Seller’s 13.8 kV breaker open/close status, and other control functions that need to be interfaced with the RTU (MW raise/lower input from Company EMS, Voltage Target Setpoint Raise/Lower from Company EMS). The separate MW and Mvar transducers with 0-1 ma output and a +/- 0.1% accuracy signal to the Company’s supervisory system. (j) A power source to Seller’s Control System that is immune to system transients which may be the plant battery, a separate Uninterruptible Power Supply, or equivalent. (k) Protective relays at Seller's Facility per Attachment A, Schedule 1 (New Switchyard Single-Line Drawing (4/13/12)) and Attachment A, Schedule 2 ( New Switchyard Relay List And Trip Scheme (4/11/12)). In the event of any conflict between the specifications, the aforesaid Attachment A, Schedule 1 and Attachment A, Schedule 2 shall control. All relay settings to shall be stamped Owned by Seller's State of Hawaii licensed electrical engineer. Relay setting to be implemented by Seller's licensed electrical contractor and verified by Company. The relays are: (1) Step up transformer differential relay to detect electrical faults within the step up transformer (SEL-387E) which will trip the 69 kV breakers in the Switchyard and the 13.8 kV breaker in Seller's Facility. (2) Step up transformer neutral ground overcurrent relay (device 350N/351N) and transformer sudden pressure relay (device 63) to detect faults within the step up transformer and trip the 69 kV breakers in the Switchyard and the 13.8 kV breaker in Seller's Facility. (3) Phase overcurrent relays (3) on the low voltage side of the step-up transformer (device 350/351) to trip the 13.8 kV circuit breaker for faults below the low voltage bushing. (4) Breaker failure relaying as shown on Schedule 1 and 2. These devices are SEL-501 breaker failure relays or equivalent. (l) Seller's generating facility switchgear and protective relays including phase overvoltage (device 59), undervoltage (device 27), voltage unbalance (device 47), reverse phase or phase unbalance (device 46), automatic lockout (device 86) set at "no restart mode", anti- motoring (device 32M), and over/under frequency (devices 810 & 81D). Relay settings to be prepared and stamped by Seller's State of Hawaii licensed electrical engineer. Relay settings to be implemented by Seller's contractors. (m) Tie breaker status and generator breaker status signals to Company supervisory control system. (iii) The Facility will comply with the recommendations of the updated February 2012 Interconnection Requirements Study and the following:;