Libya - Supporting Electricity Sector Reform (P154606) Contract No. 7181909 - Task D: Strategic Plan for Renewable Energy Development Grid Code for Renewable Sources 12th December 2017 Client: The World Bank 1818 H Street, N.W. Washington, DC 20433 Consultant: GOPA-International Energy Consultants GmbH Justus-von-Liebig-Str. 1, 61352 Bad Homburg, Germany Phone: +49-6172-1791-800; Fax: +49-6172-944 95 20 eMail: info@gopa-intec.de; www.gopa-intec.de Suntrace GmbH Grosse Elbstrasse 145c, 22767 Hamburg, Germany Phone: +49-40-767 96 38 0; Fax: +49-40-767 96 38 20 www.suntrace.de -1- Table of Contents Page Summary 1 1. Introduction 2 2. Glossary and Definitions 3 3. Connection Requirements 9 3.1 General Requirements for Power Generating Modules 9 3.1.1 Requirements for Type A Power Generating Modules 11 3.1.2 General Requirements for Type B Power Generating Modules 14 3.1.3 General Requirements for Type C Power Generating Modules 19 3.1.4 General Requirements for Type D Power Generating Modules 27 3.2 Requirements for Synchronous Power Generating Modules 30 3.2.1 Requirements for Type B Synchronous Power Generating Modules 30 3.2.2 Requirements for Type C Synchronous Power Generating Modules 30 3.2.3 Requirements for Type D Synchronous Power Generating Modules 32 3.3 Requirements for Power Park Modules 33 3.3.1 Requirements for Type B Power Park Modules 33 3.3.2 Requirements for Type C Power Park Modules 34 3.3.3 Requirements for Type D Power Park Modules 38 4. Operational Notification Procedure for Connection 39 4.1 Operation Notification Procedure for Connection of New Power Generating Modules 39 4.1.1 Provisions for Type A Power Generating Modules 39 4.1.2 Provisions for Type B, C and D Power Generating Modules 39 4.1.2.1 Additional Provisions for Type B and C Power Generating Modules 40 4.1.2.2 Additional Provisions for Type D Power Generating Modules 40 4.2 Operational Notification Procedure for Existing Power Generating Modules 51 5. Compliance 54 5.1 Compliance Monitoring 54 5.1.1 Responsibility of the Power Generating Facility Owner 54 5.1.2 Tasks of the System Operator 54 5.1.3 Common Provisions on Compliance Testing 55 5.1.4 Common Provisions on Compliance Simulations 58 5.2 Compliance Testing for Synchronous Power Generating Modules 59 5.2.1 Compliance Tests for Type B Synchronous Power Generating Modules 59 5.2.2 Compliance Tests for Type C Synchronous Power Generating Modules 60 5.2.3 Compliance Tests for Type D Synchronous Power Generating Modules 62 5.3 Compliance Testing for Power Park Modules 62 5.3.1 Compliance Tests for Type B Power Park Modules 62 5.3.2 Compliance Tests for Type C Power Park Modules 63 5.3.3 Compliance Tests for Type D Power Park Modules 66 5.4 Compliance Simulations for Synchronous Power Generating Modules 66 Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -2- Table of Contents Page 5.4.1 Compliance Simulations for Type B Synchronous Power Generating Modules 66 5.4.2 Compliance Simulations for Type C Synchronous Power Generating Modules 67 5.4.3 Compliance Simulations for Type D Synchronous Power Generating Modules 68 5.5 Compliance Simulations for Power Park Modules 69 5.5.1 Compliance Simulations for Type B Power Park Modules 69 5.5.2 Compliance Simulations for Type C Power Park Modules 70 5.5.3 Compliance Simulations for Type D Power Park Modules 71 6. Power Quality 72 6.1 Harmonics 72 6.2 Voltage Variation 73 6.2.1 Voltage Fluctuation 73 6.2.2 Voltage Unbalance 73 6.3 Frequency Variation 74 6.4 Measuring the Quality of Delivered Electric Power 74 7. Non-Compliance 75 7.1 Derogations 75 7.1.1 Request for Derogation 75 7.1.2 Decision on Derogation 76 7.1.3 Compliance of Existing Power Generating Modules 77 List of Figures Figure 3-1: Active Power Frequency Response capability of Power Generating Modules in LFSM- O Figure 3-2: Maximum power capability reduction with falling Frequency. The diagram represents the boundaries defined by the System Operator Figure 3-3: Fault-ride-through profile of a Power Generating Module. The diagram represents the lower limit of a voltage-against-time profile by the Voltage at the Interconnection Point, expressed by the ratio of its actual value and its nominal value per unit before, during and after a fault. Figure 3-4: Active Power Frequency Response capability of Power Generating Modules in LFSM- U Figure 3-5: Active Power Frequency Response capability of Power Generating Modules in FSM illustrating the case of zero deadband and insensitivity Figure 3-6: Active Power Frequency Response capability Figure 3-7: U-Q/Pmax-profile of a Synchronous Power Generating Module. The diagram represents boundaries of a U-Q/Pmax-profile by the Voltage at the Interconnection Point, expressed by the ratio of its actual value and its nominal value per unit, against the ratio of the Reactive Power (Q) and the Maximum Capacity (P max). The position, size and shape of the inner envelope are indicative. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -3- Figure 3-8: U-Q/Pmax-profile of a Power Park Module. The diagram represents boundaries of a U- Q/Pmax-profile by the Voltage at the Interconnection Point, expressed by the ratio of its actual value and its nominal value per unit, against the ratio of the Reactive Power (Q) and the Maximum Capacity (Pmax). The position, size and shape of the inner envelope are indicative. Figure 3-9: P-Q/Pmax-profile of a Power Park Module. The diagram represents boundaries of a P- Q/Pmax-profile at the Interconnection Point by the Active Power, expressed by the ratio of its actual value and the Maximum Capacity per unit, against the ratio of the Reactive Power (Q) and the Maximum Capacity (Pmax). The position, size and shape of the inner envelope are indicative. List of Tables Table 3-1: Parameters for Figure 3-3 for fault-ride-through capability of Synchronous Power Generating Modules Table 3-2: Parameters for Figure 3-3 for fault-ride-through capability of Power Park Modules Table 3-3: Parameters for Active Power Frequency Response in FSM (explanation for Figure 3-5) Table 3-4: Parameters for full activation of Active Power Frequency Response resulted from Frequency step change (explanation for Figure 3-6) Table 3-5: Minimum time periods a Power Generating Module shall be capable of operating for Voltages deviating from the nominal value at the Interconnection Point without disconnecting from the Network. (The Voltage base for p.u. values is from 66 kV to 220 kV) Table 3-6: Minimum time periods a Power Generating Module shall be capable of operating for Voltages deviating from the nominal value at the Interconnection Point without disconnecting from the Network. (The Voltage base for p.u. values is 400 kV) Table 3-7: Parameters for Figure 3-3 for fault-ride-through capability of Synchronous Power Generating Modules Table 3-8: Parameters for Figure 3-3 for fault-ride-through capability of Power Park Modules Table 6-1: Planning levels for harmonic voltages (in percent of the fundamental voltage) for system rated voltages above 1 kV Table 6-2: Compatibility levels for individual harmonic voltages in power systems up to 33 kV Table 6-3: Planning levels for flicker for system rated voltages above 1 kV Table 6-4: Compatibility levels for flicker in voltage systems up to 400 V Table 6-5: Planning levels for voltage unbalance for system rated voltages above 1 kV Table 6-6: Compatibility levels for voltage unbalance in power systems up to 33 kV Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -4- List of Abbreviations AVR Automatic Voltage Regulator CT Current transformer EON Energisation Operational Notification FON Final Operational Notification FSM Frequency Sensitive Mode HV High Voltage IEEE Institute of Electrical and Electronics Engineers intec GOPA-International Energy Consultants GmbH ION Interim Operational Notification km Kilometre kV Kilovolt kVA Kilovolt amp kWh Kilowatt hour LFSM-O Limited Frequency Sensitive Mode - Overfrequency LFSM-U Limited Frequency Sensitive Mode - Underfrequency LON Limited Operational Notification LOP List of Open Points LV Low Voltage MV Medium Voltage O&M Operations and Maintenance PGMD Power Generating Module Document PPM Power Park Module PSS Power System Stabilizer TSO Transmission System Operator Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -1- GENERAL REMARK: THIS SUMMARY IS NOT PART OF THE GRID CODE. IT DESCRIBES THE GENERAL BACKGROUND AND APPROACH AND GIVES AN OVERVIEW. BEFORE PUBLISHING THIS GRID CODE, THIS PAGE NEEDS TO BE REMOVED. Summary Initially, the Consultant task was to develop a grid code document for connecting such onshore re- newable energy projects to the Libyan power system, which we considered in other parts of the project as well. The grid code document needs to regulate a number of topics for the conventional power plants as well as it would be the first Grid Code for generator units in the Libya. The task is extended and prepared such grid code document including conventional power plants with an intention to har- monize technical requirements for renewable and conventional power plants. For the Libya case, a transition into a liberal market will take place, which organises utilities from the unique, state-owned electricity utility that is vertical structured into a bigger number of market partners. On a liberal market, there are then many stakeholders interested in power system expansions. Grid Code is a document which defines transparently and not discriminatory technical requirements as rules for all participants on the market. Thus, Grid Code should not be developed for certain projects. Grid Code shall be a common and public document for all participants on the market. For the Libya case, Grid Code represents a connection code for generation unit types. Grid Code in this report is based on ENTSO-E grid code and as such it represents the state-of-art of technical re- quirements for all types of generation units. ENSO-E is one of the strongest associations of power system operators in the world, that gathers 43 operators from 36 countries with developed and emerg- ing economy. The Grid Code will continuously undergo updates. Therefore, Grid Code in this report provides good guidelines for future development. Keeping in mind future interconnection between EN- TSO-E network and Libyan network, it has to be emphasised that all national power system operators connected to ENTSO-E network are obliged to follow rules defined by ENTSO-E. Voltage deviations have local character, while frequency deviation affects entire synchronous zone that can be caused by renewable sources penetration. Therefore, Grid Code has to define connection requirements for all voltage levels. All generation units can be classified in four generation groups ( Type A, Type B, Type C, and Type D) in accordance with rated capacity and voltage level connection. Connection requirements for all four types of generation units are divided in five main chapters: Connection requirements chapter defines technical requirements; Operational Notification Procedure for Connection chapter defines procedures for each con- nection phase. The number of connection phases depends on generation group. Operation Notification templates for Type D generation unis are provided in the report; Compliance monitoring, testing and simulations are defined in chapter Compliance; Power quality requirements for disturbing equipment, such as inverter based generation unit, is defined in chapter Power Quality; and Derogations for existing or new generation units, that cannot satisfy connection requirements defined in previous chapter, are define in chapter Non-Compliance. Finally, before publishing this general layout for a Grid Code in Libya, the local TSO needs to fine-tune on a few occasions. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -2- 1. Introduction This Connection Code defines a common framework of grid connection standards of Power Generat- ing Facilities, including Synchronous Power Generating Modules and Power Park Modules. It also de- fines a common framework of obligations for System Operator to appropriately make use of the Power Generating Facilities’ capabilities in a transparent and non -discriminatory manner ensuring a level- playing field throughout the Libya. The requirements established in this Connection Code and their applications are based on the principle of non-discrimination and transparency as well as the principle of optimisation between the highest overall efficiency and lowest total cost for all involved parties. This Connection Code is made considering: 1. ENTSO-E Connection Code, 2013 [EU]; 2. IEC/TR 61000-3-6; 3. IEC/TR 61000-3-7; 4. IEC/TR 61000-3-13; 5. EN 50160. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -3- 2. Glossary and Definitions For the purpose of this Connection Code, the following definitions shall apply: Active Power - is the real component of the Apparent Power at fundamental Frequency, expressed in watts or multiples thereof (e.g. kilowatts (kW) or megawatts (MW)). Active Power Frequency Response - is an automatic response of Active Power output from a Power Generating Module, in response to a change in system Frequency from the nominal system Frequen- cy. Alternator - is a device that converts mechanical energy into electrical energy by means of a rotating magnetic field. Ancillary Services - refer to a range of functions, which the System Operator contracts in order to guarantee system security. They include black start capability; frequency response; fast reserve; the provision of reactive power and other services. Apparent Power - is the product of Voltage and Current at fundamental Frequency. It is usually ex- pressed in kilovolt-amperes (kVA) or megavolt-amperes (MVA) and consists of a real component (Ac- tive Power) and an imaginary component (Reactive Power). Automatic Voltage Regulator (AVR) - is the continuously acting automatic equipment controlling the terminal Voltage of a Synchronous Power Generating Module by comparing the actual terminal Volt- age with a reference value and controlling by appropriate means the output of an Excitation System, depending on the deviations. Authority – is the National Regulatory Authority or similar state organised body to do administration of power system and market operation Black Start Capability - is the capability of recovery of a Power Generating Module from a total shut- down through a dedicated auxiliary power source without any energy supply which is external to the Power Generating Facility. Closed Distribution System Operator (CDSO) - is a natural or legal person operating, ensuring the maintenance of and, if necessary, developing a closed distribution Network. Compliance Monitoring - is the process to verify that the (technical) capabilities of Power Generating Modules are maintained compliant by the Power Generating Facility Owner with the specifications and requirements of this Connection Code. Compliance Simulation - is the process to verify that Power Generating Modules are compliant with the specifications and requirements of this Connection Code, for example before starting their opera- tion. The verification should include, inter alia, the revision of documentation, the verification of the re- quested capabilities of the Power Generating Module by simulation studies and the revision against actual measurements. Compliance Testing - is the process to verify that Power Generating Modules are compliant with the specifications and requirements of this Connection Code, for example before starting their operation. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -4- The verification includes, inter alia, the revision of documentation, the verification of the requested ca- pabilities of the Power Generating Module by practical tests. Connection Agreement - is a contract between the System Operator and the Power Generating Fa- cility Owner which includes the relevant site and technical specific requirements for the Power Gener- ating Facility. Control Area - is a part of the interconnected electricity transmission system controlled by a single TSO. Current - unless stated otherwise, Current refers to the root-mean-square value of the positive se- quence of the phase Current at fundamental Frequency. Derogation - is a time limited or indefinite (as specified) acceptance in writing of a non-compliance of a Power Generating Module with regard to identified requirements of this Connection Code. Droop - is the ratio of the steady-state change of Frequency (referred to nominal Frequency) to the steady-state change in power output (referred to Maximum Capacity). Distribution System Operator (DSO) - is a natural or legal person responsible for operating, ensur- ing the maintenance of and, if necessary, developing the distribution Network in a given area and, where applicable, its interconnections with other Networks and for ensuring the long-term ability of the Network to meet reasonable demands for the distribution of electricity. Energisation Operational Notification (EON) - is a notification issued by the System Operator to a Power Generating Facility Owner prior to energisation of its internal Network. An EON entitles the Power Generating Facility Owner to energise its internal Network by using the grid connection. Equipment Certificate - is a document issued by an Authorised Certifier for equipment used in Power Generating Modules confirming performance in respect of the requirements of this Connection Code. In relation to those parameters, for which this Connection Code defines ranges rather than definite values, the Equipment Certificate shall define the extent of its validity. This will identify its validity at a national or other level at which a specific value is selected from the range allowed at a Libya level. The Equipment Certificate can additionally include models confirmed against test results for the purpose of replacing specific parts of the compliance process for Type B, C and D Power Generating Modules. The Equipment Certificate will have a unique number allowing simple reference to it in the Installation Document or the Power Generating Module Document. Excitation System - is the equipment providing the field Current of a synchronous electrical machine, including all regulating and control elements, as well as field discharge or suppression equipment and protective devices. Existing Power Generating Module - is a Power Generating Module, which is not a New Power Generating Module. Evacuation Distance - is the line length between the Power Generating Facility and the Interconnec- tion Point. Final Operational Notification (FON) - is a notification issued by the System Operator to a Power Generating Facility Owner confirming that the Power Generating Facility Owner is entitled to operate Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -5- the Power Generating Module by using the grid connection because compliance with the technical de- sign and operational criteria has been demonstrated as referred to in this Connection Code. Frequency - is the Frequency of the electrical power system that can be measured in all Network are- as of the synchronous system under the assumption of a coherent value for the system in the time frame of seconds (with minor differences between different measurement locations only); its nominal value is 50 Hz. Frequency Control - is the capability of a Power Generating Module to control speed by adjusting the Active Power Output in order to maintain stable system Frequency (also acceptable as speed control for Synchronous Power Generating Modules). Frequency Response Deadband - is used intentionally to make the Frequency Control not respon- sive. In contrast to (in) sensitivity, deadband has an artificial nature and basically is adjustable. Frequency Response Insensitivity - is the inherent feature of the control system defined as the min- imum magnitude of the Frequency (input signal) which results in a change of output power (output signal). Frequency Sensitive Mode (FSM) - is a Power Generating Module operating mode which will result in Active Power output changing, in response to a change in System Frequency, in a direction which assists in the recovery to Target Frequency, by operating so as to provide Frequency Response. House load Operation - in case of Network failures resulting in disconnection of Power Generating Modules from the Network and being tripped onto their auxiliary supplies, house-load operation en- sures that Power Generating Facilities are able to continue to supply their in-house loads. Inertia - is the fact that a rotating rigid body such as an Alternator maintains its state of uniform rota- tional motion. Its angular momentum is unchanged, unless an external torque is applied. In the context of this code, this definition refers to the technologies for which Alternator speed and system Frequency are coupled. Installation Document - is a simple structured document (data/tick sheet) containing information about a Type A Power Generating Module and confirming compliance with the relevant requirements of this Connection Code. The blank Installation Document shall be available from the System Operator for the Type A Power Generating Facility Owner or alternatively the site installer on the owner’s behalf to fill in and submit to the System Operator. Instruction - is a command given orally, manually or by automatic remote control facilities, e. g. a Setpoint, from a System Operator to a Power Generating Facility Owner in order to perform an action. Interconnection Point - is the interface at which the Power Generating Module is connected to a transmission, distribution or closed distribution Network as identified in the Connection Agreement. Interim Operational Notification (ION) - is a notification issued by the System Operator to a Power Generating Facility Owner confirming that the Power Generating Facility Owner is entitled to operate the Power Generating Module by using the grid connection for a limited period of time and to under- take compliance tests to meet the technical design and operational criteria of this Connection Code. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -6- Island Operation - is the independent operation of a whole or a part of the Network that is isolated af- ter its disconnection from the interconnected system, having at least one Power Generating Module supplying power to this Network and controlling the Frequency and Voltage. Limited Frequency Sensitive Mode – Overfrequency (LFSM-O) - is a Power Generating Module operating mode which will result in Active Power output reduction in response to a change in System Frequency above a certain value. Limited Frequency Sensitive Mode – Underfrequency (LFSM-U) - is a Power Generating Module operating mode which will result in Active Power output increase in response to a change in System Frequency below a certain value. Limited Operational Notification (LON) - is a notification issued by the System Operator to a Power Generating Facility Owner which has previously reached FON status, but is temporarily subject to ei- ther a significant modification or loss of capability which has resulted in non-compliance to the Con- nection Code. Maximum Capacity - is the maximum continuous Active Power which a Power Generating Module can feed into the Network as defined in the Connection Agreement or as agreed between the System Operator and the Power Generating Facility Owner. It is also referred to in this Connection Code as Pmax. Minimum Regulating Level - is the minimum Active Power as defined in the Connection Agreement or as agreed between the System Operator and the Power Generating Facility Owner that the Power Generating Module can regulate down to and can provide Active Power control. Minimum Stable Operating Level - is the minimum Active Power as defined in the Connection Agreement or as agreed between the System Operator and the Power Generating Facility Owner, at which the Power Generating Module can be operated stably for unlimited time. Network - is plant and apparatus connected together in order to transmit or distribute electrical power. System Operator - is an entity that operates a Network. New Power Generating Module - is a Power Generating Module, for which with regard to the provisions of the initial version of this Connection Code, a final and binding con- tract of purchase of the main plant has been signed after the day, which is two years after the day of the entry into force of this Connection Code, or, with regard to the provisions of the initial version of this Connection Code, no confirmation is pro- vided by the Power Generating Facility Owner, with a delay not exceeding thirty months as from the day of entry into force of this Connection Code, that a final and binding contract of purchase of the main plant exists prior to the day, which is two years after the day of the entry into force of this Connection Code, or, with regard to the provisions of any subsequent amendment to this Connection Code and/or after any change of thresholds pursuant to the re-assessment procedure of Chapter 3.1(6), a final and binding contract of purchase of the main plant has been signed after the day, which is two years after the entry into force of any subsequent amendment to this Connection Code and/or after the entry into force of any change of thresholds pursuant to the re-assessment procedure of Chapter 3.1(6). Overexcitation Limiter - is a control device within the AVR which prevents the rotor of an Alternator from overload by limiting the excitation Current. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -7- Power Factor - is the ratio of Active Power to Apparent Power. Power Generating Facility - is a facility to convert primary energy to electrical energy which consists of one or more Power Generating Modules connected to a Network at one or more Interconnection Points. Power Generating Facility Owner - is a natural or legal entity owning a Power Generating Facility. Power Generating Module - is either a Synchronous Power Generating Module, or a Power Park Module. Power Generating Module Document (PGMD) - is a document issued by the Power Generating Fa- cility Owner to the Relevant System Operator for a Type B or C Power Generating Module. The PGMD is intended to contain information confirming that the Power Generating Module has demon- strated compliance with the technical criteria as referred to in this Connection Code and provided the necessary data and statements including a Statement of Compliance. Power Generation Modules with substantial local load - are considered to regularly operate in par- allel with the national grid but additionally largely supply the requirements of localized industrial or do- mestic loads in the project area. Consequently, the power plant, load and generation capacity consid- ered together, results into either a net import or net export electrical energy to and/or from the national grid. Power Generation Modules with minimal local loads - are considerably built to harness a source of energy. Power Park Module (PPM) - is a unit or ensemble of units generating electricity, which is connected to the Network non-synchronously or through power electronics, and has a single Interconnection Point to a transmission, distribution or closed distribution Network. Power System Stabilizer (PSS) - is an additional functionality of the AVR of a Synchronous Power Generating Module with the purpose of damping power oscillations. P-Q-Capability Diagram - describes the Reactive Power capability of a Power Generating Module in context of varying Active Power at the Interconnection Point. Reactive Power - is the imaginary component of the Apparent Power at fundamental Frequency, usually expressed in kilovar (kvar) or megavar (Mvar). Secured Fault - is defined as a fault, which is successfully cleared by Network protection according to the System Operator’s planning criteria. Setpoint - is a target value for any parameter typically used in control schemes. Significant Power Generating Module - is a Power Generating Module which is deemed significant on the basis of its impact on the cross-border system performance via influence on the control area’s security of supply, which is identified according to the criteria set forth in this Connection Code and falls within one of the categories provided in Chapter 3.1(6). Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -8- Slope - is the ratio of the change in Voltage, based on nominal Voltage, to a change in Reactive Pow- er infeed from zero to maximum Reactive Power, based on maximum Reactive Power. Statement of Compliance - is a document provided by the Power Generating Facility Owner to the System Operator stating the current status with respect to compliance itemised for each relevant ele- ment of this Connection Code. Steady-State Stability - if the Network or a Synchronous Power Generating Module previously in the steady-state reverts to this state again following a sufficiently minor disturbance, it has Steady-State Stability. Statement of Completeness (SOC) - means a statement indicating that SYSTEM OPERATOR is sat- isfied that the Power Generating Facility Owner Equipment is Compliant and requesting the Affected Network Owners to agree to the issue of the FON. Statement of Readiness (SOR) - means a statement from a User indicating that User Equipment is ready to be energised or synchronised, as appropriate. Synchronous Compensation Operation - is the operation of an Alternator without prime mover to regulate Voltage dynamically by production or absorption of Reactive Power. Synchronous Power Generating Module - is an indivisible set of installations which can generate electrical energy. It is either a single synchronous unit generating power within a Power Generating Facility directly connected to a transmission, distribution or closed distribution Network, or an ensemble of synchronous units generating power within a Power Generating Facility directly connected to a transmission, distribution or closed distribution Network with a common Intercon- nection Point, or an ensemble of synchronous units generating power within a Power Generating Facility directly connected to a transmission, distribution or closed distribution Network that cannot be operated independently from each other (e. g. units generating in a combined-cycle gas turbine facility). Synthetic Inertia - is a facility provided by a Power Park Module to replicate the effect of Inertia of a Synchronous Power Generating Module to a prescribed level of performance. System Operator - is the operator of the Network to which a Power Generating Module is or will be connected. U-Q/Pmax-profile - is a profile representing the Reactive Power capability of a Power Generating Mod- ule in context of varying Voltage at the Interconnection Point. Underexcitation Limiter - is a control device within the AVR, the purpose of which is to prevent the Alternator from losing synchronism due to lack of excitation. Voltage - unless stated otherwise, Voltage refers to the root-mean-square value of the positive se- quence of the phase-to-phase Voltages at fundamental Frequency. According to IEV 601-01-28 the boundaries between the various voltage levels are: low voltage (LV) refers to 230 V and 400 V; medium voltage (MV) refers to 11 kV and 30 kV; high voltage (HV) refers to 66 kV, 132 kV and 220 kV; extra high voltage (EHV) refers to 400 kV. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx -9- 3. Connection Requirements 3.1 General Requirements for Power Generating Modules 1. The requirements set forth by this Connection Code shall apply to New Power Generating Mod- ules in Libya. 2. The requirements set forth by this Connection Code shall apply to Existing Power Generating Modules in Libya, to the extent their applicability has been decided by the Authority, and if this has been proposed by the System Operator, following a public consultation. The proposal by the Sys- tem Operator shall be made in particular on the basis of a sound and transparent quantitative Cost-Benefit Analysis, including the costs of requiring compliance that shall demonstrate the so- cio-economic benefit of application of the requirements set forth by this Connection Code to Exist- ing Power Generating Modules. The System Operator shall have the right to re-assess, in case of factual change such as the evolution of system requirements, the applicability of the requirements set forth by this Connection Code to Existing Power Generating Modules regularly, but not more often than every three years. The System Operator shall notify the launch of the procedure for re- assessment on its website. The date of notification on the website shall constitute the first day of the launch of the procedure for re-assessment. A public consultation shall be conducted in the frame of the procedure for re-assessment. Prior to the System Operator carrying out the quantita- tive Cost-Benefit Analysis an initial qualitative comparison of costs and benefits shall be undertak- en in order to determine the cases of sizes of Power Generating Modules or types of Power Gen- erating Modules or locations of Power Generating Modules or clauses of this Connection Code for which there may be a viable case for application to Existing Power Generating Modules. Where this preparatory stage demonstrates that a subsequent analytical Cost-Benefit Analysis has a rea- sonable prospect of demonstrating positive cost-benefit, the System Operator may proceed with the full transparent quantitative Cost-Benefit Analysis. Where the preparatory stage or later stage demonstrate that applicability of the Connection Code to Existing Power Generating Modules is not required no further action is to be undertaken. 3. Existing Power Generating Modules not covered by Chapter 3.1(2) shall continue to be bound by such technical requirements that apply to them pursuant to legislation in force in Libya or contrac- tual arrangements in force. Should national legislation be repealed or cease to be in force, the Ex- isting Power Generation Module not covered by Chapter 3.1(2) shall continue to be bound by such technical requirements that applied to it pursuant to the respective national legislation such as it was the day prior to it ceasing to be in force. 4. With regard to Power Generating Modules not yet connected to the Network: a) Within a delay not exceeding thirty months as from the day of entry into force of this Connec- tion Code, the Power Generating Facility Owner shall provide the System Operator with a con- firmation of final and binding contracts it has concluded for the construction, assembly or pur- chase of the main plant of a Power Generating Module with relevance to the provisions of this Connection Code and which exists prior to the day, which is two years after the day of entry into force of this Connection Code. b) The confirmation shall at least indicate the contract title, its date of signature and of entry into force, and the specifications of the main plant to be constructed, assembled or purchased. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 10 - c) The System Operator may demand that the Authority confirms the existence, relevance and finality of such a contract, i.e. that its material terms can no longer be changed by one of the parties to the contract unilaterally and that no party to the contract has the right to terminate it at will. The Power Generating Facility Owner shall supply the Authority with all documents the Authority requests in order to ascertain that a binding and final contract exists. d) The Power Generating Module shall be considered as an Existing Power Generating Module, provided that: 1) In accordance with Chapter 3.1(4) (a) and (b) above, the System Operator is provided with sufficient evidence of the existence of binding and final contracts for the construction, assembly or purchase of the main plant of a Power Generating Module prior to the day, which is two years after the day of entry into force of this Connection Code; or 2) Following the verification performed by the Authority in accordance with Chapter 3.1(4) (c), it is ascertained that binding and final contracts for the construction, assembly or pur- chase of the main plant of a Power Generating Module exist prior to the day, which is two years after the day of entry into force of this Connection Code. e) In case the Power Generating Facility Owner does not provide the System Operator with the confirmation within the delay set forth in Chapter 3.1(4) (a), the Power Generating Module shall be considered as a New Power Generating Module. 5. The applicability and extent of the requirements a Power Generating Module has to comply with depends on the Voltage Level of its Interconnection Point and its Maximum Capacity according to the categories defined below. 6. Power Generating Modules which are considered to be Significant Power Generating Modules within the scope of this Connection Code are categorized as follows: a) A Power Generating Module is of Type A if its Interconnection Point is below or equal 1 kV or 11 kV and its Capacity is 0.8 kW or more. Requirements applicable to Type A Power Generat- ing Modules are the basic level requirements, necessary to ensure capability of generation over operational ranges with limited automated response and minimal system operator control of generation. They ensure there is no wide scale loss of generation over system operational ranges, thereby minimizing critical events, and include requirements necessary for wide spread intervention during system critical events. b) A Power Generating Module is of Type B if its Interconnection Point is below or equal 66 kV and its Capacity is 0.2 MW or more. The definition of the threshold shall be coordinated with the adjacent System Operator and Distribution Licensee and shall be reviewed by the Authori- ty. The Power Generating Facility Owner shall assist and contribute to this determination of the threshold and provide the relevant data as requested by the System Operator. The Sys- tem Operator shall have the right to re-assess the determination of the threshold regularly, if relevant circumstances have changed materially, but not more often than every three years. A public consultation shall be conducted in the frame of the procedure for re-assessment. Fol- lowing any change to thresholds any Power Generating Module that has been moved to a new type will not automatically have to comply retroactively with the additional requirements but will be subject to the same procedure as applied to Existing Power Generating Modules in line Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 11 - with Chapter 4.2. Requirements applicable to Type B Power Generating Modules provide a wider level of automated dynamic response with higher resilience to more specific operational events to ensure use of this higher dynamic response and a higher level system operator con- trol and information to utilize these capabilities. They ensure automated response to alleviate and maximize dynamic generation response to system events, greater Power Generating Module resilience of these events to ensure this dynamic response and better communication and control to leverage these capabilities. c) A Power Generating Module is of Type C if its Interconnection Point is below or equal 66 kV and its Capacity is 5 MW or more. The definition of the threshold shall be coordinated with the adjacent System Operator and Distribution Licensee and shall be reviewed by the Authority. The Power Generating Facility Owner shall assist and contribute to this determination of the threshold and provide the relevant data as requested by the System Operator. The System Operator shall have the right to re-assess the determination of the threshold regularly, if rele- vant circumstances have changed materially, but not more often than every three years. A public consultation shall be conducted in the frame of the procedure for re-assessment. Fol- lowing any change to thresholds any Power Generating Module that has been moved to a new type will not automatically have to comply retroactively with the additional requirements but will be subject to the same procedure as applied to Existing Power Generating Modules in line with Chapter 4.2. Requirements applicable to Type C Power Generating Modules provide re- fined, stable and highly controllable (real time) dynamic response to provide principle ancillary services to ensure security of supply. These requirements cover all operational Network states with consequential detailed specification of interactions of requirements, functions, control and information to utilize these capabilities. They ensure real time system response necessary to avoid, manage and respond to system events. These requirements provide sufficient genera- tion functionality to respond to both intact and system disturbed situations, and the need for in- formation and control necessary to utilize this generation over this diversity of situations. d) A Power Generating Module is of Type D if its Interconnection Point is above 66 kV . A Syn- chronous Power Generating Module or Power Park Module is of Type D as well if its Intercon- nection Point is below 66 kV and its Capacity is 15 MW. The definition of the threshold shall be coordinated with the adjacent System Operator and Distribution Licensee and shall be re- viewed by the Authority. The Power Generating Facility Owner shall assist and contribute to this determination of the threshold and provide the relevant data as requested by the System Operator. The System Operator shall have the right to re-assess the determination of the threshold regularly, if relevant circumstances have changed materially, but not more often than every three years. A public consultation shall be conducted in the frame of the procedure for re-assessment. Following any change to thresholds any Power Generating Module that has been moved to a new type will not automatically have to comply retroactively with the ad- ditional requirements but will be subject to the same procedure as applied to Existing Power Generating Modules in line with Chapter 4.2. Requirements applicable to Type D Power Gen- erating Modules are in particular specific for higher Voltage connected generation with impact on entire system control and operation. 3.1.1 Requirements for Type A Power Generating Modules 1. Type A Power Generating Modules shall fulfil the following requirements referring to Frequency stability: a) With regard to Frequency ranges: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 12 - 1) A Power Generating Module shall be capable of staying connected to the Network and operating within the Frequency ranges and time periods specified in IEEE Std. C37.106. 2) Wider Frequency ranges or longer minimum times for operation can be agreed between the System Operator and the Power Generating Facility Owner to ensure the best use of the technical capabilities of a Power Generating Module if needed to preserve or to re- store system security. If wider Frequency ranges or longer minimum times for operation are economically and technically feasible, the consent of the Power Generating Facility Owner shall not be unreasonably withheld. 3) While respecting the provisions of Chapter 3.1.1(1) (a) point 1) a Power Generating Mod- ule shall be capable of automatic disconnection at specified frequencies, if required by the System Operator. Terms and settings for automatic disconnection shall be agreed be- tween the System Operator and the Power Generating Facility Owner. b) With regard to the rate of change of Frequency withstand capability, a Power Generating Module shall be capable of staying connected to the Network and operating at rates of change of Frequency up to a value defined by the System Operator other than triggered by rate-of- change-of-Frequency-type of loss of mains protection. This rate-of-change-of-Frequency-type of loss of mains protection will be defined by the System Operator and subject to notification to the Authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework. c) With regard to the Limited Frequency Sensitive Mode - Overfrequency (LFSM-O) the following shall apply: 1) The Power Generating Module shall be capable of activating the provision of Active Power Frequency Response according to Figure 3-1 at a Frequency threshold between and in- cluding 50.2 Hz and 50.5 Hz with a Droop in a range of 2 – 12 %. The actual Frequency threshold and Droop settings shall be determined by the System Operator subject to noti- fication to the Authority. The modalities of that notification shall be determined in accord- ance with the applicable national regulatory framework. The Power Generating Module shall be capable of activating Active Power Frequency Response as fast as technically feasible with an initial delay that shall be as short as possible and reasonably justified by the Power Generating Facility Owner to the System Operator if greater than 2 seconds. The Power Generating Module shall be capable of either continuing operation at Minimum Regulating Level when reaching it or further decreasing Active Power output in this case, as defined by the System Operator. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 13 - P Pref f1 fn f fn s2 Synchronous Power Generating Modules: Pref is the Maximum Capacity Power Park Modules: Pref is the actual Active Power output at the moment the LFSM-O threshold is reached or the Maximum Capacity, as defined by the System Operator Figure 3-1: Active Power Frequency Response capability of Power Generating Modules in LFSM-O Notes: Pref is the reference Active Power to which ΔP is related and may be defined dif- ferently for Synchronous Power Generating Modules and Power Park Modules. ΔP is the change in Active Power output from the Power Generating Module. fn is the nominal Fre- quency (50 Hz) in the Network and Δf is the Frequency change in the Network. At overfrequencies where Δf is above Δf1 the Power Generating Module has to provide a negative Active Power output change according to the Droop s2. 2) The Power Generating Module shall be capable of stable operation during LFSM-O opera- tion. When LFSM-O is active, the LFSM-O Setpoint will prevail over any other Active Pow- er Setpoints. d) The Power Generating Module shall be capable of maintaining constant output at its target Ac- tive Power value regardless of changes in Frequency, unless output shall follow the defined changes in output in the context of Chapter 3.1.1(1) (c), (e) or Chapter 3.1.3(2) (b), and Chap- ter 3.1.3(2) (c) where applicable. e) The System Operator shall define admissible Active Power reduction from maximum output with falling Frequency within the boundaries, given by the full lines in Figure 3-2: – Below 49 Hz falling by a reduction rate of 2 % of the Maximum Capacity at 50 Hz per 1 Hz Frequency drop; – Below 49.5 Hz by a reduction rate of 10 % of the Maximum Capacity at 50 Hz per 1 Hz Frequency drop. Applicability of this reduction is limited to a selection of affected generation technologies and may be subject to further conditions defined by the System Operator. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 14 - P Pmax 48 f [Hz] 48.5 49 49.5 50 5% 10% Figure 3-2: Maximum power capability reduction with falling Frequency. The diagram repre- sents the boundaries defined by the System Operator f) The Power Generating Module shall be equipped with a logic interface (input port) in order to cease Active Power output within less than 5 seconds following an Instruction from the Sys- tem Operator. The System Operator shall have the right to define the requirements for further equipment to make this facility operable remotely. g) The System Operator shall define the conditions under which a Power Generating Module shall be capable of connecting automatically to the Network. These conditions shall include: – frequency ranges, within which an automatic connection is admissible, and a correspond- ing delay time; and – maximum admissible gradient of increase of Active Power output. Automatic connection is allowed unless determined otherwise by the System Operator. 3.1.2 General Requirements for Type B Power Generating Modules 1. In addition to fulfilling the requirements listed in Chapter 3.1.1, Type B Power Generating Modules shall fulfil the requirements in this Chapter. 2. Type B Power Generating Modules shall fulfil the following requirements referring to Frequency stability: a) In order to be able to control Active Power output, the Power Generating Module shall be equipped with an interface (input port) in order to be able to reduce Active Power output as in- structed by the System Operator. The System Operator shall have the right to define the re- quirements for further equipment to make this facility operable remotely. 3. Type B Power Generating Modules shall fulfil the following requirements referring to robustness of Power Generating Modules: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 15 - a) With regard to fault-ride-through capability of Power Generating Modules: 1) the System Operator shall define a voltage-against-time-profile according to Figure 3-3 at the Interconnection Point for fault conditions which describes the conditions in which the Power Generating Module shall be capable of staying connected to the Network and continuing stable operation after the power system has been disturbed by Secured Faults on the Network. U/p.u. 1.0 Urec2 Urec1 Uclear Uret 0 tclear trec1 trec2 trec3 t/sec Figure 3-3: Fault-ride-through profile of a Power Generating Module. The diagram repre- sents the lower limit of a voltage-against-time profile by the Voltage at the Inter- connection Point, expressed by the ratio of its actual value and its nominal val- ue per unit before, during and after a fault. Notes: Uret is the retained Voltage at the Interconnection Point during a fault, tclear is the instant when the fault has been cleared. Urec1, Urec2, trec1, trec2 and trec3 specify cer- tain points of lower limits of Voltage recovery after fault clearance. 2) This voltage-against-time-profile shall be expressed by a lower limit of the course of the phase-to-phase Voltages on the Network Voltage level at the Interconnection Point during a symmetrical fault, as a function of time before, during and after the fault. This lower limit is defined by the System Operator using parameters in Figure 3-3 according to Table 3-1 and Table 3-2. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 16 - Table 3-1: Parameters for Figure 3-3 for fault-ride-through capability of Synchronous Pow- er Generating Modules Voltage parameters [p.u.] Time parameters [seconds] Uret: 0.05 – 0.3 tclear: 0.14 – 0.25 Uclear: 0.7 – 0.9 trec1: tclear Urec1: Uclear trec2: trec1 – 0.7 Urec2: 0.85 – 0.9 and ≥ Uclear trec3: trec2 – 1.5 Table 3-2: Parameters for Figure 3-3 for fault-ride-through capability of Power Park Mod- ules Voltage parameters [p.u.] Time parameters [seconds] Uret: 0.05 – 0.15 tclear: 0.14 – 0.25 Uclear: Uret – 0.15 trec1: tclear Urec1: Uclear trec2: trec1 Urec2: 0.85 trec3: 1.5 – 3.0 3) The System Operator shall define and make publicly available defining the pre-fault and post-fault conditions for the fault-ride-through capability in terms of: – conditions for the calculation of the pre-fault minimum short circuit capacity at the Interconnection Point; – conditions for pre-fault active and Reactive Power operating point of the Power Generating Module at the Interconnection Point and Voltage at the Interconnec- tion Point; and – conditions for the calculation of the post-fault minimum short circuit capacity at the Interconnection Point. 4) The System Operator shall provide on request by the Power Generating Facility Own- er the pre-fault and post-fault conditions to be considered for fault-ride-through capa- bility as an outcome of the calculations at the Interconnection Point as defined in Chapter 3.1.2(3) (a) point 3) regarding: – pre-fault minimum short circuit capacity at each Interconnection Point expressed in MVA; – pre-fault operating point of the Power Generating Module expressed in Active Power output and Reactive Power output at the Interconnection Point and Volt- age at the Interconnection Point; and – post-fault minimum short circuit capacity at each Interconnection Point expressed in MVA. Alternatively generic values for the above conditions derived from typical cases may be provided by the System Operator. 5) The Power Generating Module shall be capable of staying connected to the Network and continue stable operation when the actual course of the phase-to-phase Voltages on the Network Voltage level at the Interconnection Point during a symmetrical fault, given the pre-fault and post-fault conditions according to Chapter 3.1.2(3) (a) points 3) and 4), remains above the lower limit defined in Chapter 3.1.2(3) (a) point 2), unless Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 17 - the protection scheme for internal electrical faults requires the disconnection of the Power Generating Module from the Network. The protection schemes and settings for internal electrical faults shall be designed not to jeopardize fault-ride-through perfor- mance. 6) While still respecting Chapter 3.1.2(3) (a) point 5), undervoltage protection (either fault-ride-through capability or minimum Voltage defined at the Interconnection Point Voltage) shall be set by the Power Generating Facility Owner to the widest possible technical capability of the Power Generating Module unless the System Operator re- quires less wide settings according to Chapter 3.1.2(5) (b). The settings shall be justi- fied by the Power Generating Facility Owner in accordance with this principle. 7) Fault-ride-through capabilities in case of asymmetrical faults shall be defined by the System Operator. 4. Type B Power Generating Modules shall fulfil the following requirement referring to system resto- ration: a) With regard to capability of reconnection after an incidental disconnection due to a Network disturbance, the System Operator shall adopt a decision defining the conditions, under which a Power Generating Module shall be capable of reconnecting to the Network after an inci- dental disconnection has taken place due to a Network disturbance. Installation of automatic reconnection systems shall be subject to prior authorization by the System Operator. 5. Type B Power Generating Modules shall fulfil the following general system management require- ments: a) With regard to control schemes and settings 1) Schemes and settings of the different control devices of the Power Generating Module relevant for transmission system stability and to enable emergency actions shall be coordinated and agreed between the System Operator and the Power Generating Fa- cility Owner. 2) Any changes to the schemes and settings of the different control devices of the Power Generating Module, relevant for transmission and distribution system stability and to enable emergency actions, shall be coordinated and agreed between the System Op- erator and the Power Generating Facility Owner, especially if they concern the cir- cumstances referred to under Chapter 3.1.2(5) (a) point 1). b) With regard to electrical protection schemes and settings: 1) The System Operator shall define the schemes and settings necessary to protect the Network taking into account the characteristics of the Power Generating Module. Pro- tection schemes relevant for the Power Generating Module and the Network and set- tings relevant for the Power Generating Module shall be coordinated and agreed be- tween the System Operator and the Power Generating Facility Owner. The protection schemes and settings for internal electrical faults shall be designed not to jeopardize the performance of a Power Generating Module according to these Connection Code requirements otherwise. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 18 - 2) Electrical protection of the Power Generating Module shall take precedence over op- erational controls taking into account system security, health and safety of staff and the public and mitigation of the damage to the Power Generating Module. 3) Protection schemes can protect against the following aspects: – external and internal short circuit; – asymmetric load (Negative Phase Sequence); – stator and rotor overload; – over-/underexcitation; – over-/undervoltage at the Interconnection Point; – over-/undervoltage at the Alternator terminals; – inter-area oscillations; – inrush Current; – asynchronous operation (pole slip); – protection against inadmissible shaft torsions (for example, subsynchronous resonance); – Power Generating Module line protection; – unit transformer protection; – backup schemes against protection and switchgear malfunction; – overfluxing (U/f); – inverse power; – rate of change of Frequency; and – neutral Voltage displacement. 4) Any changes to the protection schemes relevant for the Power Generating Module and the Network and to the setting relevant for the Power Generating Module shall be agreed between the System Operator and the Power Generating Facility Owner and be concluded prior to the introduction of changes. c) With regard to priority ranking of protection and control, the Power Generating Facility Owner shall organize its protections and control devices in compliance with the following priority rank- ing, organized in decreasing order of importance: – Network system and Power Generating Module protection; – Synthetic Inertia, if applicable; – Frequency control (Active Power adjustment); – Power Restriction; and – Power gradient constraint. d) With regard to information exchange: 1) Power Generating Facilities shall be capable of exchanging information between the Power Generating Facility Owner and the System Operator in real time or periodically with time stamping as defined by the System Operator. 2) The System Operator shall define the contents of information exchanges and the pre- cise list and time of data to be facilitated. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 19 - 3.1.3 General Requirements for Type C Power Generating Modules 1. In addition to fulfilling the requirements listed in Chapters 3.1.1 and 3.1.2, except for Chapter 3.1.1(1) (f) and Chapter 3.1.2(2) (a), Type C Power Generating Modules shall fulfil the require- ments in this Chapter. 2. Type C Power Generating Modules shall fulfil the following requirements referring to Frequency stability: a) With regard to Active Power controllability and control range, the Power Generating Module control system shall be capable of adjusting an Active Power Setpoint as instructed by the System Operator to the Power Generating Facility Owner. It shall be capable of implementing the Setpoint within a period specified in the above Instruction and within a tolerance defined by the System Operator (subject to the availability of the prime mover resource), subject to no- tification to the Authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework. Manual, local measures shall be possible in the case that any automatic remote control devices are out of service. b) In addition to Chapter 3.1.1(1) (c) the following shall apply accumulatively with regard to Lim- ited Frequency Sensitive Mode – Underfrequency (LFSM-U): 1) The Power Generating Module shall be capable of activating the provision of Active Power Frequency Response according to Figure 3-4 at a Frequency threshold be- tween and including 49.8 Hz and 49.5 Hz with a Droop in a range of 2 – 12 %. In the LFSM-U mode the Power Generating Module shall be capable of providing a power increase up to its Maximum Capacity. The actual delivery of Active Power Frequency Response in LFSM-U mode depends on the operating and ambient conditions of the Power Generating Module when this response is triggered, in particular limitations on operation near Maximum Capacity at low frequencies according to Chapter 3.1.1(1) (e) and available primary energy sources. The actual Frequency threshold and Droop settings shall be determined by the System Operator, subject to notification to the Au- thority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework. The Active Power Frequency Response shall be activated as fast as technically feasible with an initial delay that shall be as short as possible and reasonably justified by the Power Generating Facility Owner to the System Operator if greater than 2 seconds. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 20 - P Pref Synchronous Power Generating Modules: Pref is the Maximum Capacity Power Park Modules: Pref is the actual Active Power output at the moment the LFSM-O threshold is reached or the Maximum Capacity, as defined by the System Operator s2 f1 f fn fn Figure 3-4: Active Power Frequency Response capability of Power Generating Modules in LFSM-U Notes: Pref is the reference Active Power to which ΔP is related and may be defined differently for Synchronous Power Generating Modules and Power Park Modules. ΔP is the change in Active Power output from the Power Generating Module. f n is the nominal Frequency (50 Hz) in the Network and Δf is the Frequency change in the Network. At underfrequencies where Δf is below Δf1 the Power Generating Module has to provide a positive Active Power output change according to the Droop S2. 2) Stable operation of the Power Generating Module during LFSM-U operation shall be ensured. The LFSM-U reference Active Power shall be the Active Power output at the moment of activation of LFSM-U and shall not be changed unless triggered by fre- quency restoration action. c) In addition to Chapter 3.1.3(2) (b) the following shall apply accumulatively, when operating in Frequency Sensitive Mode (FSM): 1) The Power Generating Module shall be capable of providing Active Power Frequency Response with respect to Figure 3-5 and in accordance with the parameters specified by the System Operator within the ranges shown in Table 3-3. This specification shall be subject to notification to the Authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework. 2) In case of overfrequency the Active Power Frequency Response is limited by the Min- imum Regulating Level. 3) In case of underfrequency the Active Power Frequency Response is limited by Maxi- mum Capacity. The actual delivery of Active Power Frequency Response depends on the operating and ambient conditions of the Power Generating Module when this re- sponse is triggered, in particular limitations on operation near Maximum Capacity at low frequencies and available primary energy sources. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 21 - 4) The Frequency Response Deadband of Frequency deviation and Droop are selected by the System Operator and must be able to be reselected subsequently (without re- quiring to be online or remote) within the given frames in Table 3-3, subject to notifica- tion to the Authority. The modalities of that notification shall be determined in accord- ance with the applicable national regulatory framework. 5) As a result of a frequency step change, the Power Generating Module shall be capa- ble of activating full Active Power Frequency Response, at or above the full line ac- cording to Figure 3-6 in accordance with the parameters specified by the System Op- erator (aiming at avoiding Active Power oscillations for the Power Generating Module) within the ranges according to Table 3-4. This specification shall be subject to notifica- tion to the Authority. The modalities of that notification shall be determined in accord- ance with the applicable national regulatory framework. The combination of choice of the parameters according to Table 3-4 shall take into account possible technology de- pendent limitations. The initial delay of activation shall be as short as possible and reasonably justified by the Power Generating Facility Owner to the System Operator, by providing technical evidence for why a longer time is needed, if greater than 2 sec- onds or a shorter time if specified by the System Operator for generation technologies without Inertia. 6) Each Power Generating Module shall be capable of increasing output as it is defined in Table 3-4, when the frequency falls (limited to 105 % Maximum Continuous Rating for thermal generating units and 110 % Maximum Continuous Rating for hydro gener- ating units). Ramping back to the previous MW level (in case the increased output level cannot be sustained) shall not be faster than 1 % per minute. P Pmax P1 Pmax s1 f fn P1 Pmax Figure 3-5: Active Power Frequency Response capability of Power Generating Modules in FSM illustrating the case of zero deadband and insensitivity Notes: Pmax is the Maximum Capacity to which ΔP is related. ΔP is the change in Ac- tive Power output from the Power Generating Module. fn is the nominal Frequency (50 Hz) in the Network and Δf is the Frequency deviation in the Network. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 22 - P Pmax P1 Pmax t1 t/s t2 Figure 3-6: Active Power Frequency Response capability Notes: Pmax is the Maximum Capacity to which ΔP is related. ΔP is the change in Ac- tive Power output from the Power Generating Module. The Power Generating Mod- ules have to provide Active Power Output ΔP up to the point ΔP1 in accordance with the times t1 and t2 with the values of ΔP1, t1and t2 being specified by the System Op- erator according to Table 3-4. t1 is the initial delay. t2 is the time for full activation. Table 3-3: Parameters for Active Power Frequency Response in FSM (explanation for Fig- ure 3-5) Parameters Ranges P1 Active Power range related to Maximum Capacity 1.5 – 10 % Pmax f1 10 – 30 mHz Frequency Response Insensitivity f1 0.02 – 0.06 % fn Frequency Response Deadband 0 – 500 mHz Droop S1 2 – 12 % Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 23 - Table 3-4: Parameters for full activation of Active Power Frequency Response resulted from Frequency step change (explanation for Figure 3-6) Parameters Ranges Active Power range related to Maximum Capacity (Frequency P1 1.5 – 10 % response range) Pmax Maximum admissible initial delay unless justified otherwise 2 seconds for generation technologies with Inertia Maximum admissible initial delay unless justified otherwise As specified by for generation technologies without Inertia System Operator Maximum admissible choice of full activation time , unless longer activation times are admitted by the System Operator 30 seconds due to system stability reasons d) With regard to Frequency restoration control, the Power Generating Module shall provide functionalities compliant to specifications defined by the System Operator, aiming at restoring Frequency to its nominal value and/ or maintain power exchange flows between control areas at their scheduled values. e) With regard to disconnection due to underfrequency, any Power Generating Facility with sub- stantial load, shall be capable of disconnecting its load in case of underfrequency. f) With regard to real-time monitoring of FSM: 1) To monitor the operation of Active Power Frequency Response the communication in- terface shall be equipped to transfer on-line from the Power Generating Facility to the Network control centre of the System Operator on request by the System Operator at least the following signals: – status signal of FSM (on/off); – actual parameter settings for Active Power Frequency Response; and – Droop and dead band. – Telecom failure – Number of farm units available – Number of farm units unavailable – Number of farm units under maintenance – Total MW infeed – Total Mvar – Voltage level – Farm rated maximum MW output – Farm current maximum MW output – Temperature – Wind speed – Wind direction – Cloud covering – CB/Switch status 2) The System Operator shall define additional signals to be provided by the Power Generating Facility for monitoring and/or recording devices in order to verify the per- Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 24 - formance of the Active Power Frequency Response provision of participating Power Generating Modules. 3. Type C Power Generating Modules shall fulfil the following requirements referring to Voltage sta- bility: a) The System Operator shall have the right to specify Voltages at the Interconnection Point at which a Power Generating Module shall be capable of automatic disconnection. The terms and settings for this automatic disconnection shall be defined by the System Operator. 4. Type C Power Generating Modules shall fulfil the following requirements referring to robustness of Power Generating Modules: a) In case of power oscillations, Steady-state Stability of a Power Generating Module is required when operating at any operating point of the P-Q-Capability Diagram. A Power Generating Module shall be capable of staying connected to the Network and operating without power re- duction notwithstanding the provisions of Chapter 3.1.1(1) (e), as long as Voltage and Fre- quency remain within the admissible limits pursuant to this Connection Code. b) Single-phase or three-phase auto-reclosures on meshed Network lines, if applicable to this Network, shall be withstood by Power Generating Modules without tripping. Details of this ca- pability shall be subject to coordination and agreements on protection schemes and settings according to Chapter 3.1.2(5), (b). 5. Type C Power Generating Modules shall fulfil the following requirements referring to system resto- ration: a) With regard to Black Start Capability: 1) Black Start Capability is not mandatory. If the System Operator deems system securi- ty to be at risk to a lack of Black Start Capability in a Control Area, the System Opera- tor shall have the right to obtain a quote for Black Start Capability from Power Gener- ating Facility Owners. 2) A Power Generating Module with a Black Start Capability shall be able to start from shut down within a timeframe decided by the System Operator, without any external energy supply. The Power Generating Module shall be able to synchronise within the Frequency limits defined in Chapter 3.1.1(1) and Voltage limits defined by the System Operator or defined by Chapter 3.1.4(2) where applicable. 3) The Power Generating Module Voltage regulation shall be capable of regulating load connections causing dips of Voltage automatically. The power-generating module with black start capability shall: – be capable of regulating load connections in block load; – control Frequency in case of overfrequency and underfrequency within the whole Active Power output range between Minimum Regulating Level and Maximum Capacity as well as at house load level; – be capable of parallel operation of a few Power Generating Modules within one island; and Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 25 - – control Voltage automatically during the system restoration phase. b) With regard to capability to take part in Island Operation: 1) The capability to take part in Island Operation, if required by the System Operator, shall be possible within the Frequency limits defined in Chapter 3.1.1(1) and Voltage limits according to Chapter 3.1.3(3) or Chapter 3.1.4(2) where applicable. 2) If required, the Power Generating Module shall be able to operate in FSM during Is- land Operation, as defined in Chapter 3.1.3(2) (b). In the case of a power surplus, it shall be possible to reduce the Active Power Output of the Power Generating Module from its previous operating point to any new operating point within the P-Q-Capability Diagram as much as inherently technically feasible, but at least an Active Power out- put reduction to 55 % of its Maximum Capacity shall be possible. 3) Detection of change from interconnected system operation to Island Operation shall not rely solely on the System Operator’s switchgear position signals. The detection method shall be agreed between the Power Generating Facility Owner and the Sys- tem Operator. 4) The generator breaker and bus bar at generator voltage be provided for Island Opera- tion. 5) For Island Operation synchronizing arrangement should be made from generator breakers as well as from interconnecting LV/MV grid breaker. 6) Control performance of the voltage control loop shall be such that under isolated op- erating conditions the damping coefficient shall be above 0.25 for the entire operating range. c) With regard to quick re-synchronization capability: 1) Quick re-synchronization capability is required in case of disconnection of the Power Generating Module from the Network in line with the protection strategy agreed be- tween the System Operator and the Power Generating Facility Owner in the event of disturbances to the system. 2) The Power Generating Module whose minimum re-synchronization time after its dis- connection from any external power supply exceeds 15 minutes shall be designed for tripping to house load from any operating point in its P-Q-Capability Diagram. For identifying house load operation any System Operator’s switchgear position signals may be used only as additional information which cannot be solely relied on. 3) Power Generating Modules shall be capable of continuing operation following tripping to house load, irrespective of any auxiliary connection to the external Network. The minimum operation time shall be defined by the System Operator taking into consid- eration the specific characteristics of the prime mover technology. 6. Type C Power Generating Modules shall fulfil the following general system management require- ments: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 26 - a) With regard to loss of angular stability or loss of control, a Power Generating Module shall be capable of disconnecting automatically from the Network in order to support preservation of system security and/or to prevent damage from the Power Generating Module. The Power Generating Facility Owner and the System Operator shall agree on the criteria to detect loss of angular stability or loss of control. b) With regard to instrumentation: 1) Power Generating Facilities shall be equipped with a facility to provide fault recording and dynamic system behaviour monitoring of the following parameters: – Voltage; – Active Power; – Reactive Power; and – Frequency. The System Operator shall have the right to define quality of supply parameters to be complied with provided a reasonable prior notice is given. 2) The settings of the fault recording equipment, including triggering criteria and the sampling rates shall be agreed between the Power Generating Facility Owner and the Authority in coordination with the System Operator. 3) The dynamic system behaviour monitoring shall include an oscillation trigger, speci- fied by the System Operator, detecting poorly damped power oscillations of the Tur- bine speed control below 3 % for gas turbines and 5 % for steam turbine. 4) The facilities for quality of supply and dynamic system behaviour monitoring shall in- clude arrangements for the Power Generating Facility Owner, the System Operator to access the information. The communications protocols for recorded data shall be agreed between the Power Generating Facility Owner and the System Operator. c) With regard to the simulation models: 1) The System Operator shall have the right to require the Power Generating Facility Owner to provide simulation models, that shall properly reflect the behaviour of the Power Generating Module in both steady-state and dynamic simulations (50 Hz com- ponent) and, where appropriate and justified, in electromagnetic transient simulations. The decision shall include: – the format in which models shall be provided – the provision of documentation of models structure and block diagrams The models shall be verified against the results of compliance tests as of Chapters 5.2 and 5.3. They shall then be used for the purpose of verifying the requirements of this Connection Code including but not limited to Compliance Simulations as of Chapters 5.4 and 5.5 and for use in studies for continuous evaluation in system planning and operation. 2) For the purpose of dynamic simulations, the models provided shall contain the follow- ing sub-models, depending on the existence of the mentioned components: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 27 - – Alternator and prime mover; – Speed and power control; – Voltage control, including, if applicable, Power System Stabilizer (PSS) func- tion and excitation system; – Power Generating Module protection models as agreed between the System Operator and the Power Generating Facility Owner; and – Converter models for Power Park Modules. 3) The System Operator shall deliver to the Power Generating Facility Owner an esti- mate of the minimum and maximum short circuit capacity at the Interconnection Point, expressed in MVA, as an equivalent of the Network. 4) The System Operator shall have the right to require Power Generating Module record- ings in order to compare the response of the models with these recordings. d) With regard to the installation of devices for system operation and/or security, if the System Operator considers additional devices necessary to be installed in a Power Generating Facility in order to preserve or restore system operation or security, the System Operator and the Power Generating Facility Owner shall investigate this request and agree on an appropriate solution. e) The System Operator shall define minimum and maximum limits on rates of change of Active Power output (ramping limits) in both up and down direction for a Power Generating Module taking into consideration the specific characteristics of the prime mover technology. f) With regard to earthing arrangement of the neutral-point at the Network side of step-up trans- formers, transformer shall be connected with grounded star on low voltage side and delta on high voltage side. g) With regard to changes to, modernization of or replacement of equipment of Power Generat- ing Modules, any Power Generating Facility Owner intending to change plant and equipment of the Power Generating Module that may have an impact on the grid connection and on the interaction, such as turbines, Alternators, converters, high-voltage equipment, protection and control systems (hardware and software), shall notify in advance (in accordance with agreed or decided national timescales) the System Operator in case it is reasonable to foresee that these intended changes may be affected by the requirements of this Connection Code and shall agree on these requirements before the proposals are implemented with the System Op- erator. In case of modernisation or replacement of equipment in existing Power Generating Modules the new equipment shall comply with the respective requirements which are relevant to the planned work. The use of existing spare components that do not comply with the re- quirements has to be agreed with the System Operator in each case. 3.1.4 General Requirements for Type D Power Generating Modules 1. In addition to fulfilling the requirements listed in Chapters 3.1.1, 3.1.2, and 3.1.3 unless referred to otherwise in this Chapter, except for Chapter 3.1.1(1) (f), (g), Chapter 3.1.2(2) (a) and Chapter 3.1.3(3) (a), Type D Power Generating Modules shall fulfil the requirements in this Chapter. 2. Type D Power Generating Modules shall fulfil the following requirements referring to Voltage sta- bility: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 28 - a) With regard to Voltage ranges: 1) While still respecting the provisions according to Chapters 3.1.2(3) (a) and 3.1.4(3) (a), a Power Generating Module shall be capable of staying connected to the Network and operating within the ranges of the Network Voltage at the Interconnection Point, expressed by the Voltage at the Interconnection Point related to nominal Voltage (per unit), and the time periods specified by Table 3-5 and Table 3-6. Table 3-5: Minimum time periods a Power Generating Module shall be capable of operating for Voltages deviating from the nominal value at the Interconnection Point with- out disconnecting from the Network. (The Voltage base for p.u. values is from 66 kV to 220 kV) Voltage Range Time period for operation 0.85 p.u. – 0.90 p.u 60 minutes 0.90 p.u. – 1.118 p.u. Unlimited 1.118 p.u. – 1.15 p.u. Not less than 20 minutes Table 3-6: Minimum time periods a Power Generating Module shall be capable of operating for Voltages deviating from the nominal value at the Interconnection Point with- out disconnecting from the Network. (The Voltage base for p.u. values is 400 kV) Voltage Range Time period for operation 0.85 p.u. – 0.90 p.u 60 minutes 0.90 p.u. – 1.05 p.u. Unlimited 1.05 p.u. – 1.0875 p.u. Not less than 60 minutes 2) Wider Voltage ranges or longer minimum times for operation can be agreed between the System Operator and the Power Generating Facility Owner to ensure the best use of the technical capabilities of a Power Generating Module if needed to preserve or to restore system security. If wider Voltage ranges or longer minimum times for opera- tion are economically and technically feasible, the consent of the Power Generating Facility Owner shall not be unreasonably withheld. 3) While still respecting the provisions of Chapter 3.1.4(2) (a) point 1), the System Oper- ator shall have the right to specify Voltages at the Interconnection Point at which a Power Generating Module shall be capable of automatic disconnection. The terms and settings for automatic disconnection shall be agreed between the System Opera- tor and the Power Generating Facility Owner. 3. Type D Power Generating Modules shall fulfil the following requirements referring to robustness of Power Generating Modules: b) With regard to fault-ride-through capability of Power Generating Modules: 1) The voltage-against-time-profile shall be defined by the System Operator using pa- rameters in Figure 3-3 according to Table 3-7 and Table 3-8. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 29 - 2) The System Operator shall define and make publicly available the pre-fault and post- fault conditions for the fault-ride-through capability according to Chapter 3.1.2(3) (a) point 3). Table 3-7: Parameters for Figure 3-3 for fault-ride-through capability of Synchronous Pow- er Generating Modules Voltage parameters [p.u.] Time parameters [seconds] Uret: 0 tclear: 0.14 – 0.25 Uclear: 0.25 trec1: tclear – 0.45 Urec1: 0.5 – 0.7 trec2: trec1 – 0.7 Urec2: 0.9 trec3: trec2 – 1.5 Table 3-8: Parameters for Figure 3-3 for fault-ride-through capability of Power Park Mod- ules Voltage parameters [p.u.] Time parameters [seconds] Uret: 0 tclear: 0.14 – 0.25 Uclear: Uret trec1: tclear Urec1: Uclear trec2: trec1 Urec2: 0.85 trec3: 1.5 – 3.0 3) The System Operator shall provide on request by the Power Generating Facility Own- er the pre-fault and post-fault conditions to be considered for fault-ride-through capa- bility as an outcome of the calculations at the Interconnection Point as defined in Chapter 3.1.2(3) (a) point 3) regarding: – pre-fault minimum short circuit capacity at each Interconnection Point ex- pressed in MVA; – pre-fault operating point of the Power Generating Module expressed in Active Power output and Reactive Power output at the Interconnection Point and Voltage at the Interconnection Point; and – post-fault minimum short circuit capacity at each Interconnection Point ex- pressed in MVA. 4) Fault-ride-through capabilities in case of asymmetrical faults shall be defined by the System Operator. 4. Type D Power Generating Modules shall fulfil the following general system management require- ments: a) With regard to synchronization, when starting a Power Generating Module, synchronization shall be performed by the Power Generating Facility Owner after authorization by the System Operator. The Power Generating Module shall be equipped with the necessary synchroniza- tion facilities. Synchronization of Power Generating Modules shall be possible for frequencies within the ranges set out in IEEE Std. C37.106. The System Operator and the Power Generat- ing Facility Owner shall agree on the settings of synchronization devices to be concluded prior Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 30 - to operation of the Power Generating Module. An agreement shall cover the following matters: Voltage, Frequency, phase angle range, phase sequence, deviation of Voltage and Frequen- cy. 3.2 Requirements for Synchronous Power Generating Modules 3.2.1 Requirements for Type B Synchronous Power Generating Modules 1. In addition to fulfilling the requirements listed in Chapters 3.1.1 and 3.1.2, Type B Synchronous Power Generating Modules shall fulfil the requirements in this Chapter. 2. Type B Synchronous Power Generating Modules shall fulfil the following requirements referring to Voltage stability: a) With regard to Reactive Power capability the System Operator shall have the right to define the capability of a Synchronous Power Generating Module to provide Reactive Power. b) With regard to the Voltage control system, a Synchronous Power Generating Module shall be equipped with a permanent automatic excitation control system in order to provide constant Alternator terminal Voltage at a selectable Setpoint without instability over the entire operating range of the Synchronous Power Generating Module. 3. Type B Synchronous Power Generating Modules shall fulfil the following requirements referring to robustness of Power Generating Modules: a) With regard to post fault Active Power recovery after fault-ride-through, the System Operator shall define magnitude and time for Active Power recovery the Power Generating Module shall be capable of providing. 3.2.2 Requirements for Type C Synchronous Power Generating Modules 1. In addition to fulfilling the requirements listed in Chapters 3.1.1, 3.1.2, 3.1.3 and 3.2.1, except for Chapter 3.1.1(1) (f), Chapter 3.1.2(2) (a) and Chapter 3.2.1(2) (a), Type C Synchronous Power Generating Modules shall fulfil the requirements in this Chapter. 2. Type C Synchronous Power Generating Modules shall fulfil the following requirements referring to Frequency stability: a) Under all system operating conditions, the Power Generating Module speed shall not exceed 103 % corresponding to 51.5 Hz in the interconnection with EAPP system. b) The speed rise due to full load rejection under Island Operation should not be more than 35 % or even lower in case of special (large motor) load characteristics. In case Island Operation is not required, the speed rise on full load rejection can be increased up to 55 % - 60 %. 3. Type C Synchronous Power Generating Modules shall fulfil the following requirements referring to Voltage stability: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 31 - a) With regard to Reactive Power Capability, for Synchronous Power Generating Modules where the Interconnection Point is not at the location of the high-voltage terminals of the step-up transformer to the Voltage level of the Interconnection Point nor at the Alternator terminals, if no step-up transformer exists, supplementary Reactive Power may be defined by the System Operator, to compensate for the Reactive Power demand of the high-voltage line or cable be- tween these two points from the responsible owner of this line or cable. b) With regard to Reactive Power capability at Maximum Capacity: 1) The System Operator shall define the Reactive Power provision capability require- ments in the context of varying Voltage. For doing so, it shall define a U-Q/Pmax- profile that shall take any shape within the boundaries of which the Synchronous Power Generating Module shall be capable of providing Reactive Power at its Maxi- mum Capacity. 2) The U-Q/Pmax-profile is defined by the System Operator in conformity with the follow- ing principles: – the U-Q/Pmax-profile shall not exceed the U-Q/Pmax-profile envelope, repre- sented by the inner envelope in Figure 3-7; – the position of the U-Q/Pmax-profile envelope within the limits of the fixed outer envelope in Figure 3-7. U/p.u. Fixed Outer Envelope 1.10 Inner Envelope 1.05 Voltage Range 1.00 Q/Pmax Range 0.95 0.90 Q/Pmax 0.85 0.10 0.20 0.30 0.40 0.50 0.60 0.70 - 0.60 - 0.50 - 0.40 - 0.30 - 0.20 - 0.10 0.00 Consumption (lead) Production (lag) Figure 3-7: U-Q/Pmax-profile of a Synchronous Power Generating Module. The diagram rep- resents boundaries of a U-Q/Pmax-profile by the Voltage at the Interconnection Point, expressed by the ratio of its actual value and its nominal value per unit, against the ratio of the Reactive Power (Q) and the Maximum Capacity (P max). The position, size and shape of the inner envelope are indicative. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 32 - 3) The Reactive Power provision capability requirement applies at the Interconnection Point. For profile shapes other than rectangular, the Voltage range represents the highest and lowest values. The full Reactive Power range is therefore not expected to be available across the range of steady-state Voltages. 4) The Synchronous Power Generating Module shall be capable of moving to any oper- ating point within its U-Q/Pmax profile in appropriate timescales to target values re- quested by the System Operator. c) With regard to Reactive Power capability below Maximum Capacity, when operating at an Ac- tive Power output below the Maximum Capacity (P<Pmax), the Synchronous Power Generating Modules shall be capable of operating in every possible operating point in the P-Q Capability Diagram of the Alternator of this Synchronous Power Generating Module at least down to Min- imum Stable Operating Level. Even at reduced Active Power output, Reactive Power supply at the Interconnection Point shall fully correspond to the P-Q-Capability Diagram of the Alternator of this Synchronous Power Generating Module, taking the auxiliary supply power and the Ac- tive and Reactive Power losses of the step-up transformer, if applicable, into account. 3.2.3 Requirements for Type D Synchronous Power Generating Modules 1. In addition to fulfilling the requirements listed in Chapters 3.1.1, 3.1.2, 3.1.3, 3.1.4, 3.2.1 and 3.2.2, except for Chapter 3.1.1(1) (f), Chapter 3.1.2(2) (a), Chapter 3.1.3(3) (a), and Chapter 3.2.1(2), Type D Synchronous Power Generating Modules shall fulfil the requirements in this Chapter. 2. Type D Synchronous Power Generating Modules shall fulfil the following requirements referring to Voltage stability: a) The parameters and settings of the components of the Voltage control system shall be agreed between the Power Generating Facility Owner and the System Operator. Such agreement shall include: – specifications and performance of an Automatic Voltage Regulator (AVR) with regards to steady-state Voltage and transient Voltage control; and – specifications and performance of the Excitation System: bandwidth limitation of the output signal to ensure that the highest Frequency of re- sponse cannot excite torsional oscillations on other Power Generating Modules con- nected to the Network; an Underexcitation Limiter to prevent the Automatic Voltage Regulator from reducing the Alternator excitation to a level which would endanger synchronous stability; an Overexcitation Limiter to ensure that the Alternator excitation is not limited to less than the maximum value that can be achieved whilst ensuring the Synchronous Power Generating Module is operating within its design limits; a stator Current limiter; and a PSS function to attenuate power oscillations, if the Synchronous Power Generating Module size is above a value of Maximum Capacity defined by the System Operator. 3. Type D Synchronous Power Generating Modules shall fulfil the following requirements referring to robustness of Power Generating Modules: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 33 - a) Technical capabilities in order to aid angular stability under fault conditions (e. g. fast valving or braking resistor) shall be implemented if allowed or requested by the System Operator. The specifications shall be agreed between the System Operator and the Power Generating Facili- ty Owner. 3.3 Requirements for Power Park Modules 3.3.1 Requirements for Type B Power Park Modules 1. In addition to fulfilling the general requirements listed in Chapter 3.1.1 and 3.1.2, Type B Power Park Modules shall fulfil the requirements in this Chapter. 2. Type B Power Park Modules shall fulfil the following requirements referring to Voltage stability: a) With regard to Reactive Power capability the System Operator shall have the right to define the capability of a Power Park Module to provide Reactive Power. b) The System Operator shall have the right to require fast acting additional reactive Current in- jection at the Interconnection Point to the pre-fault reactive Current injection in case of sym- metrical (3-phase) faults: 1) The Power Park Module shall be capable of activating this additional reactive Current injection during the period of faults. The Power Park Module shall be capable of ei- ther: a. ensuring the supply of the additional reactive Current at the Interconnection Point according to further specifications by the System Operator of the magni- tude of this Current, depending on the deviation of the Voltage at the Intercon- nection Point from its nominal value; or b. alternatively, measuring Voltage deviations at the terminals of the individual units of the Power Park Module and providing an additional reactive Current at the terminals of these units according to further specifications by the System Operator of the magnitude of this Current, depending on the deviation of the Voltage at units’ terminals from its nominal value. 2) The Power Park Module (Chapter 3.3.1(2) (b) point 1) option a.) or the individual units of the Power Park Module (Chapter 3.3.1(2) (b) point 1) option b.) shall be capable of providing at least 2/3 of the additional reactive Current within a time period specified by the System Operator, which shall not be less than 10 milliseconds. The target val- ue of this additional reactive Current defined by Chapter 3.3.1(2) (b) point 1) shall be reached with an accuracy of 10 % within 60 milliseconds from the moment the Voltage deviation has occurred as further specified according to Chapter 3.3.1(2) (b) point 1). 3) The total reactive Current contribution shall be not more than 1 p.u. of the short term dynamic Current rating (covering up to 0.6 seconds) of the Power Park Module (Chap- ter 3.3.1(2) (b) point 1) option a.) or of the individual units of the Power Park Module (Chapter 3.3.1(2) (b) point 1) option b.) taking into account the pre-fault reactive Cur- rent. If additional real Current injection is given priority over additional reactive Current injection, the total Current contribution can be further limited by the real Current based Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 34 - on limiting the apparent Current (vector addition of real and reactive Current) to 1 p.u. of the short term dynamic Current rating of the Power Park Module (Chapter 3.3.1(2) (b) point 1) option a.) or the individual units of the Power Park Module (Chapter 3.3.1(2) (b) point 1) option b.). c) With regard to fast acting additional reactive Current injection in case of asymmetrical (1- phase or 2-phase) faults the System Operator shall have the right to introduce a requirement for asymmetrical Current injection. 3. Type B Power Park Modules shall fulfil the following requirements referring to robustness of Power Generating Modules: a) With regard to post fault Active Power recovery after fault-ride-through, the Power Park Mod- ules shall provide at least 90 % of its maximum available Active Power as quickly as possible and in any event within 1 second of the voltage recovering to the normal operating range. 3.3.2 Requirements for Type C Power Park Modules 1. In addition to fulfilling the requirements listed in Chapters 3.1.1, 3.1.2, 3.1.3, and 3.3.1, except for Chapter 3.1.1(1) (f), Chapter 3.1.2(2) (a), and Chapter 3.3.1(2) (a) unless referred to otherwise in Chapter 3.3.2(3) (d) points 3) and 4), Type C Power Park Modules shall fulfil the requirements in this Chapter. 2. Type C Power Park Modules shall fulfil the following requirements referring to Frequency stability: a) With regard to the capability of providing Synthetic Inertia to a low Frequency event: 1) The Power Park Module control system shall be capable of operating the Power Park Module at a reduced level if the Active Power output has been restricted by the System Operator. The Power Park Module control system shall be capable of receiving an on-line Active Power Control Set-point sent by the System Operator and shall commence imple- mentation of the Setpoint within 10 seconds of receipt of the signal from the System Op- erator. The rate of change of output to achieve the Active Power Control Set-point should be no less than the maximum ramp rate settings of the Power Park Module control sys- tem, as advised by the System Operator. 2) The Power Park Modules control system shall be capable of controlling the ramp rate of its Active Power output with a maximum MW per minute ramp rate set by the System Operator. There shall be two maximum ramp rate settings. The first ramp rate setting shall apply to the MW ramp rate averaged over 1 minute. The second ramp rate setting shall apply to the MW per minute ramp rate averaged over ten 10 minutes. These ramp rate settings shall be applicable for all ranges of operation including start up, normal op- eration and shut down. It is recognised that decreasing primary power source or frequen- cy response may cause either of the maximum ramp rate settings to be exceeded. It shall be possible to vary each of these two maximum ramp rate settings independently over a range between 1 and 20 MW per minute. The Wind Turbine Generator control sys- tem shall have the capability to set the ramp rate in MW per minute averaged over both 1 and 10 minutes. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 35 - 3) The Power Park Modules operator and the System Operator shall agree a procedure for setting and changing the ramp rate control. 3. Type C Power Park Modules shall fulfil the following requirements referring to Voltage stability: a) With regard to Reactive Power Capability, for Power Park Modules where the Interconnection Point is not at the location of the high-voltage terminals of its step-up transformer nor at the terminals of the high-voltage line or cable to the Interconnection Point at the Power Park Mod- ule, if no step-up transformer exists, supplementary Reactive Power may be required by the System Operator to compensate for the Reactive Power demand of the high-voltage line or cable between these two points from the responsible owner of this line or cable. b) With regard to Reactive Power capability at Maximum Capacity: 1) The System Operator shall define the Reactive Power provision capability require- ments in the context of varying Voltage. For doing so, it shall define a U-Q/Pmax-profile that shall take any shape within the boundaries of which the Power Park Module shall be capable of providing Reactive Power at its Maximum Capacity. 2) The U-Q/Pmax-profile is defined by the System Operator in conformity with the follow- ing principles: – the U-Q/Pmax-profile shall not exceed the U-Q/Pmax-profile envelope, represented by the inner envelope in Figure 3-8, its shape does not need to be rectangular; and – the position of the U-Q/Pmax-profile envelope within the limits of the fixed outer envelope in Figure 3-8. U/p.u. Fixed Outer Envelope 1.10 Inner Envelope 1.05 Voltage Range 1.00 Q/Pmax Range 0.95 0.90 Q/Pmax 0.85 0.10 0.20 0.30 0.40 0.50 0.60 0.70 - 0.60 - 0.50 - 0.40 - 0.30 - 0.20 - 0.10 0.00 Consumption (lead) Production (lag) Figure 3-8: U-Q/Pmax-profile of a Power Park Module. The diagram represents boundaries of a U-Q/Pmax-profile by the Voltage at the Interconnection Point, expressed by the Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 36 - ratio of its actual value and its nominal value per unit, against the ratio of the Reactive Power (Q) and the Maximum Capacity (P max). The position, size and shape of the inner envelope are indicative. 3) The Reactive Power provision capability requirement applies at the Interconnection Point. For profile shapes other than rectangular, the Voltage range represents the highest and lowest values. The full Reactive Power range is therefore not expected to be available across the range of steady-state Voltages. c) With regard to Reactive Power capability below Maximum Capacity: 1) The System Operator shall define the Reactive Power provision capability require- ments. For doing so, it shall define a P-Q/Pmax-profile that shall take any shape within the boundaries of which the Power Park Module shall be capable of providing Reac- tive Power below Maximum Capacity. 2) The P-Q/Pmax-profile is defined by the System Operator, in conformity with the follow- ing principles: – the P-Q/Pmax-profile shall not exceed the P-Q/Pmax-profile envelope, represented by the inner envelope in Figure 3-9; – the Active Power range of the P-Q/Pmax-profile envelope at zero Reactive Power shall be 1 p.u.; – the P-Q/Pmax-profile can be of any shape and shall include conditions for Reactive Power capability at zero Active Power; and – the position of the P-Q/Pmax-profile envelope within the limits of the fixed outer envelope in Figure 3-9. 3) When operating at an Active Power output below the Maximum Capacity (P<Pmax), the Power Park Module shall be capable of providing Reactive Power at any operating point inside its P-Q/Pmax-profile, if all units of this Power Park Module, which generate power, are technically available (i. e. not out-of-service due to maintenance or failure). Otherwise the Reactive Power capability may be less taking into consideration the technical availabilities. 4) The Power Park Module shall be capable of moving to any operating point within its P- Q/Pmax profile in appropriate timescales to target values requested by the System Op- erator. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 37 - P/p.u. Outer Envelope 1.00 0.90 Inner Envelope 0.80 0.70 Q/Pmax Range 0.60 0.50 0.40 0.30 under-excited over-excited operation operation 0.20 0.10 Q/Pmax 0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 - 0.60 - 0.50 - 0.40 - 0.30 - 0.20 - 0.10 0.00 Consumption (lead) Production (lag) Figure 3-9: P-Q/Pmax-profile of a Power Park Module. The diagram represents boundaries of a P-Q/Pmax-profile at the Interconnection Point by the Active Power, expressed by the ratio of its actual value and the Maximum Capacity per unit, against the ratio of the Reactive Power (Q) and the Maximum Capacity (P max). The position, size and shape of the inner envelope are indicative. d) With regard to Reactive Power control modes: 1) The Power Park Module shall be capable of providing Reactive Power automatically by either Voltage Control mode, Reactive Power Control mode or Power Factor Con- trol mode. 2) For the purposes of Voltage Control mode, the Power Park Module shall be capable of contributing to Voltage control at the Interconnection Point by provision of Reactive Power exchange with the Network with a Setpoint Voltage covering at least 0.95 to 1.05 p.u. in steps no greater than 0.01 p.u. with a Slope with a range of at least 2 to 7 % in steps no greater than 0.5 %. The Reactive Power output shall be zero when the grid Voltage value at the Interconnection Point equals the Voltage Setpoint. The Setpoint may be operated with or without a deadband selectable in a range from zero to ±5 % of nominal Network Voltage in steps no greater than 0.5 %. Following a step change in Voltage, the Power Park Module shall be capable of achieving 90 % of the change in Reactive Power output within a time t 1 to be specified by the System Operator in the range of 1 – 5 seconds and settle at the value defined by the operating Slope within a time t2 to be specified by the System Operator in the range of 5 – 60 seconds, with a steady-state reactive tolerance no greater than 5 % of the maximum Reactive Power. 3) For the purposes of Reactive Power Control mode, the Power Park Module shall be capable of setting the Reactive Power Setpoint anywhere in the Reactive Power Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 38 - range, defined by Chapter 3.3.1(2) (a) and by Chapter 3.3.2(3) (a) and (b), with setting steps no greater than 5 Mvar or 5 % (whichever is smaller) of full Reactive Power, controlling the Reactive Power at the Interconnection Point to an accuracy within ±5 Mvar or ±5 % (whichever is smaller) of the full Reactive Power. 4) For the purposes of Power Factor Control mode, the Power Park Module shall be ca- pable of controlling the Power Factor at the Interconnection Point within the required Reactive Power range, defined by the System Operator according to Chapter 3.3.1(2) (a) or defined by Chapter 3.3.2(3) (a) and (b), with a target Power Factor in steps no greater than 0.01. The System Operator shall define the target Power Factor value and the tolerance expressed in Mvar or % of the Reactive Power value issued from conversion of Power Factor value, within a period of time, following a sudden change of Active Power output. 5) The System Operator shall define which of the above three reactive power control mode options and associated Setpoints shall apply and further equipment to make the adjustment of the relevant Setpoint operable remotely. e) With regard to priority to Active or Reactive Power contribution, the System Operator shall de- fine, whether Active Power contribution or Reactive Power contribution has priority during faults for which fault-ride-through capability is required. If priority is given to Active Power con- tribution, its provision shall be established no later than 150 ms from the fault inception. f) With regard to power oscillations damping control, if required by the System Operator a Power Park Module shall be capable of contributing to damping power oscillations. The voltage and reactive power control characteristics of Power Park Modules shall not adversely affect the damping of power oscillations. g) During Power Park Module start up, the Power Park Module shall ensure that the reactive power draw (inrush currents in case of induction generators) shall not affect the grid perfor- mance. 3.3.3 Requirements for Type D Power Park Modules 1. Type D Power Park Modules shall fulfil the requirements listed in Chapters 3.1.1, 3.1.2, 3.1.3, 3.1.4, 3.3.1 and 3.3.2, except for Chapter 3.1.1(1) (f), Chapter 3.1.2(2) (a), Chapter 3.1.3(3) (a), and Chapter 3.3.1(2) (a). Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 39 - 4. Operational Notification Procedure for Connection 4.1 Operation Notification Procedure for Connection of New Power Generating Modules 4.1.1 Provisions for Type A Power Generating Modules 1. The operational notification procedure for connection of each new Type A Power Generating Module shall consist of an Installation Document. Based on the Installation Document obtained from the System Operator, the Power Generating Facility Owner shall fill in the required infor- mation and submit it to the System Operator. For subsequent Power Generating Modules sepa- rate independent Installation Documents shall be provided. 2. The content of the Installation Document shall be defined by the System Operator, at least con- taining the following: a) the location at which the connection is made; b) the date of the connection; c) the Maximum Capacity of the installation in kW; d) the type of primary energy source; e) the classification of the Power Generating Module as an emerging technology; f) reference to Equipment Certificates issued by an authorised certifier used in the site installa- tion; g) for equipment used, which has not received an Equipment Certificate, information shall be provided as directed by the System Operator; and h) the contact details of the Power Generating Facility Owner and the installer and their signa- tures. 3. On permanent decommissioning of a Power Generating Module the Power Generating Facility Owner shall notify the System Operator in writing. 4.1.2 Provisions for Type B, C and D Power Generating Modules 1. The operational notification procedure for connection of each new Type B, C and D Power Gen- erating Module allows for the use of an Equipment Certificate issued by an authorised certifier. 2. The Equipment Certificate issued by an authorised certifier is intended to collate verified data and performance for a specific make and type of Power Generating Module. The purpose of this pro- cess is to repeatedly use this data, where relevant, to verify specific parts of data and perfor- mance in place of part of the Operational Notification Procedure. 3. The Equipment Certificate issued by an authorised certifier cannot indicate total compliance, but can be used as validated information about components of the Power Generating Module. The Power Generating Facility Owner is advised to check with the System Operator at an early stage Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 40 - of a project what parts, if any, are acceptable instead of the full compliance process and how to proceed to make use of this facility. 4.1.2.1 Additional Provisions for Type B and C Power Generating Modules 1. The operational notification procedure for connection of each new Type B and C Power Generat- ing Module shall comprise a Power Generating Module Document (PGMD). The PGMD provided by the Power Generating Facility Owner shall contain information as defined by the System Oper- ator, including a Statement of Compliance. The selection of the required content of the PGMD shall be defined by the System Operator. Its content shall comprise the information defined in Chapters 4.1.2.2 to 4.1.2.2.3.1 for Type D Power Generating Modules, but can be simplified through delivery in a single stage of operational notification as well as reduced requirements of de- tails. The Power Generating Facility Owner shall provide the required information and submit it to the System Operator. For subsequent Power Generating Modules separate independent PGMDs shall be provided. 2. The System Operator on acceptance of a complete and adequate PGMD shall issue a Final Op- erational Notification to the Power Generating Facility Owner. 3. On permanent decommissioning of a Power Generating Module the Power Generating Facility Owner shall notify the System Operator in writing. 4.1.2.2 Additional Provisions for Type D Power Generating Modules 1. The operational notification procedure for connection for each new Type D Power Generating Module shall comprise: a) Energisation Operational Notification (EON); b) Interim Operational Notification (ION);and c) Final Operational Notification (FON). 4.1.2.2.1 Energisation Operational Notification (EON) for Type D Power Generating Modules 1. An Energisation Operational Notification (EON) shall entitle the Power Generating Facility Owner to energise its internal Network and auxiliaries for the Power Generating Modules by using the grid connection that is defined by the Interconnection Point. 2. An Energisation Operational Notification (EON) shall be issued by the System Operator, subject to completion of preparation including agreement on the protection and control settings relevant to the Interconnection Point between the System Operator and the Power Generating Facility Owner. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 41 - 4.1.2.2.1.1 Example of Network Owner Agreement for Energisation System Operator Ref address Ref address Date Libya Contact Telephone no Dear Sirs [Power Station]– Agreement for Energisation [Network Owner] and Libya SYSTEM OPERATOR are parties to a Network Owner Construction Agreement dated [date] in respect of [Power Station] (“the Site”) which facilitates the connection of the Site to the National Electricity Transmission/Distribution System or use of the National Electricity Transmission/Distribution System in respect of the Site. SYSTEM OPERATOR has received a Statement of Readiness (SOR) from the Power Generation Fa- cility Owner, and has asked Network Owner that the Power Generation Facility Owner Equipment can be energised as specified in the SOR attached to this letter. [Network Owner] hereby confirms its agreement, that System Operator may issue an Energisation No- tice consistent with the attached SOR. Should you require any further information please contact [[Network Owner], telephone [telephone number]. [Network Owner] Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 42 - 4.1.2.2.1.2 Example of Energisation Operation Notification Date: [ ] Our Ref: [ ] Your Ref: [ ] System Operator address For the Attention of [ ] address Libya Company Secretary [ ] [ ] [ ] [ ] Tel No: ########### [ ] Fax No: ########### Mobile: ########### #######@System Operator.com [power station] – Energisation of [xxx] EFFECTIVE FROM [xxx] Dear Sirs Libya SYSTEM OPERATOR and [party] are parties to a Bilateral Connection Agreement] [Bilateral Embedded Generation Agreement] (the “Bilateral agreement” [and Construction Agreement] (the "Construction Agreement") dated [date] providing for [connection to and] [use of] the National Electrici- ty Transmission/Distribution System at [connection site] [site of connection]. You have notified System Operator of your readiness to energise [equipment] at [location] on [date]. SYSTEM OPERATOR confirms that with effect from the [date], the Power Generation Facility Owner’s [Equipment] for [power station] at [location] can be energised and remain, energised for the sole pur- pose of Commissioning the Power Generation Facility Owner Equipment and taking demand from the National Electricity Transmission/Distribution System. Such right is without prejudice to the exercise of any rights SYSTEM OPERATOR may have under the Grid Code and Bilateral Agreement, including without limitation the Disconnection and/or De Energisation of the Power Generation Facility Owner Equipment. Please note that the individual Generating Plant cannot be instructed to synchronise until SYSTEM OPERATOR has issued an Interim Operational Notification in respect of [power station]. Terms defined in the Connection Code, the Bilateral Agreement, [the Construction Agreement] and the Grid Code have the same meaning in this letter. Should you require any further information regarding this matter please contact [ ] on tele- phone number [###########] or e-mail #######@System Operator.com. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 43 - 4.1.2.2.2 Interim Operational Notification (ION) for Type D Power Generating Modules 1. An Interim Operational Notification (ION) shall entitle the Power Generating Facility Owner to op- erate the Power Generating Module and generate power by using the grid connection for a limited period of time. 2. An Interim Operational Notification (ION) shall be issued by the System Operator, subject to the completion of data and study review process as required by this Connection Code. 3. With respect to data and study review the System Operator shall have the right to request the fol- lowing from the Power Generating Facility Owner: a) itemized Statement of Compliance; b) detailed technical data of the Power Generating Module with relevance to the grid connection as specified by the System Operator; c) Equipment Certificates of Power Generating Module, issued by an authorised certifier, where these are relied upon as part of the evidence of compliance; d) simulation models as specified by Chapter 3.1.3(6) (c) and as required by the System Opera- tor; e) studies demonstrating expected steady-state and dynamic performance as required by Chap- ters 5.4 or 5.5 of this Connection Code; and f) details of intended compliance tests according to Chapters 5.2 and 5.3. 4. The maximum period for the Power Generating Facility Owner to remain in the Interim Operational Notification (ION) status shall not exceed twenty-four months. The System Operator is entitled to specify a shorter ION validity period. The ION validity period shall be subject to notification to the Authority. The modalities of that notification shall be determined in accordance with the applicable national regulatory framework. ION extensions shall be granted only if the Power Generating Fa- cility Owner has made substantial progress towards full compliance. At the time of ION extension, the outstanding issues should be explicitly identified. 5. A prolongation of the maximum period for the Power Generating Facility Owner to remain in the Interim Operational Notification (ION) status (beyond a total of twenty-four months) may be grant- ed upon request for derogation made to the System Operator before the expiry of that period in accordance with the derogation procedure. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 44 - 4.1.2.2.2.1 Example of Network Owner Agreement for Interim Operational Notification System Operator Ref address Ref address Date Libya Name Telephone no Dear Sirs [Power Station]– Interim Operational Notification [Network Owner] and Libya SYSTEM OPERATOR are parties to a Network Owner Construction Agreement dated [date] in respect of [Power Station] (“the Site”) which facilitates the connection of the Site to the National Electricity Transmission/Distribution System or use of the National Electricity Transmission/Distribution System in respect of the Site. SYSTEM OPERATOR has received notification of the Power Generation Facility Owner’s intention to synchronise generating units at the Site on or after [date]. There are a number of matters which are unresolved at the present. These must be resolved before [Network Owner] can consent to SYSTEM OPERATOR issuing a final Operational Notification in re- spect of the Site. These issues are summarised in the attached Schedule of Unresolved Compliance issues. The unresolved matters do not however form grounds for [Network Owner] preventing SYS- TEM OPERATOR from issuing an interim Operational Notification (ION). [Network Owner] hereby confirms its agreement, that SYSTEM OPERATOR may issue an ION effec- tive from [Start Date] to [End Date] (“the Term”) subject to the condition that significant progress is made towards the resolution of the unresolved issues within the timescales listed in the schedule dur- ing the Term. On completion of the Term, [Network Owner] will decide whether to permit SYSTEM OPERATOR to issue a further ION for a fixed period or a FON. This letter is issued without prejudice to the exercise of any rights [Network Owner] may have under or pursuant to the Grid Code, the Connection Code or the Network Owner Construction Agreement. Should you require any further information please contact [Network Owner Contact], telephone [tele- phone number]. [Network Owner] Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 45 - 4.1.2.2.2.2 Example of Interim Operational Notification Document Date: [ ] Our Ref: [ ] Your Ref: [ ] System Operator address For the Attention of [ ] address Libya Company Secretary [ ] [ ] [ ] [ ] Tel No: ########### [ ] Fax No: ########### Mobile: ########### #######@System Operator.com [power station] – Interim Operational Notification EFFECTIVE FROM [xxx] TO [xxx] Dear Sirs Libya SYSTEM OPERATOR and [party] are parties to a [Bilateral Connection Agreement]/[Bilateral Embedded Generator Agreement]/[Bilateral Embedded Large Licence Exemptable Agreement] (the “Bilateral Agreement”).and [Construction Agreement] (the “Construction Agreement”) dated [date] providing for [connection to and use] / [use] of the National Electricity Transmission/Distribution Sys- tem at [connection site] [site of connection]. You have notified SYSTEM OPERATOR of your intention to synchronise the [unit/power station] on or after [day, date]. Under the [Construction Agreement] [Bilateral Agreement] SYSTEM OPERATOR is required to notify you that the provisions of the Bilateral Agreement [and the Construction Agreement] have been complied with (if that is the case) and that [unit/power station ] at the [Connection Site] [site of connection] can therefore become Operational (an “Operational Notification”). There are a number of matters which are unresolved at present which must be resolved before SYS- TEM OPERATOR can issue a Final Operational Notification (“FON”) in respect of [Connection Site] [site of connection]. The current situation is summarised in the attached Schedule of Unresolved Compliance Issues. The unresolved matters do not however prevent SYSTEM OPERATOR from issu- ing an Interim Operational Notification (ION). SYSTEM OPERATOR therefore confirms the issue of an ION effective from [date] to [date] (the “Term”) subject to the condition that significant progress be made towards the resolution of the unr e- Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 46 - solved issues within the timescales listed in the schedule during the Term. On completion of the Term SYSTEM OPERATOR will decide whether to issue a further ION for a fixed period or an FON. This ION is issued without prejudice to the exercise of any rights SYSTEM OPERATOR may have un- der the Grid Code, the Construction Agreement and Bilateral Agreement, including without limitation the Disconnection and/or De Energisation of the User’s Equipment. Terms defined in the Connection Code, the Construction Agreement, the Bilateral Agreement and the Grid Code have the same meaning in this letter. Should you require any further information regarding this matter or the attached schedule please con- tact [ ] on telephone [###########] or e-mail #######@System Operator.com. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 47 - [ ] Connection Site\Site of Connection Schedule of Unresolved Compliance Issues in respect of [unit ] as at [date] Item IC* Ref Issue – Brief Description Programme to Contact SYSTEM OP- Resolve Includ- ERATOR/Customer ing Expected End Date 1 2 3 4 5 6 7 8 9 10 Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 48 - 4.1.2.2.2.3 Proforma for Statement of Completeness (SOC) Date: [ ] Our Ref: [ ] Dear Sirs [Power Station / Site] – Statement of Completeness SYSTEM OPERATOR and [Network Owner] (“the Network Owner”) are parties to a Construction Agreement dated [ ] in respect of the [Power Station / Site (“Site”) which facilitates the connection of the Site to the National Electricity Transmission/Distribution System or use of the National Electricity Transmission/Distribution System in respect of the Site. On [ ], and with the agreement of [the Network Owner] dated [ ], SYSTEM OPERATOR issued an Interim Operational Notification ("ION") in respect of the Site which has subsequently been extended to remain in force until [ ]. The unresolved issues associated with the ION were set out in the ‘Schedule of Unresolved Compliance Issues’ attached to the ION dated [ ] which was sent to the Power Generating Facility Owner and copied to the Network Owner. The ION was issued subject to the condition that significant progress be made towards the resolution of the un- resolved issues. SYSTEM OPERATOR can confirm that these issues have now progressed to the point where it is SYSTEM OPERATOR’s intention to issue a Final Operational Notification (“FON”) for the Site with ef- fect from [ ] subject to the Network Owner’s agreement. Accordingly, SYSTEM OPERATOR requests the Network Owner to indicate their agreement by signing and dating this Statement of Com- pleteness below and returning a copy to SYSTEM OPERATOR. In the event that the Network Owner’s does not agree to the issue of a FON in respect of the Site SYSTEM OPERATOR requests that the Network Owner respond within five business days stating why a FON should not be issued. In taking this step SYSTEM OPERATOR confirms that it has passed all the relevant plant perfor- mance data to the Network Owner and will maintain this information. Signing box for SYSTEM OPERATOR Signing box for the Network Owner, in turn Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 49 - 4.1.2.2.3 Final Operational Notification (FON) for Type D Power Generating Modules 1. A Final Operational Notification (FON) shall entitle the Power Generating Facility Owner to operate the Power Generating Module by using the grid connection. 2. A Final Operational Notification (FON) shall be issued by the System Operator, upon prior removal of all incompatibilities identified for the purpose of the Interim Operational Notification (ION) status and subject to the completion of data and study review process as required by this Connection Code. 3. With respect to data and study review the following must be submitted to the System Operator by the Power Generating Facility Owner: a) itemized Statement of Compliance; and b) update of applicable technical data, simulation models and studies as referred to in Chapter 4.1.2.2.1.1(3) (b), (c), (d) and (e), including use of actual measured values during testing. 4. In case of incompatibility identified for the purpose of the granting of the Final Operational Notifica- tion (FON), derogation may be granted upon request made to the System Operator, in accordance with the derogation procedure. A Final Operational Notification (FON) shall be issued by the Sys- tem Operator, if the Power Generating Module is compliant with the provisions of the derogation. The System Operator shall have the right to refuse the operation of the Power Generating Module, whose owner’s request for derogation was rejected, until the Power Generating Facility Owner and the System Operator have established a resolution of the incompatibility and the Power Generat- ing Module is considered to be compliant by the System Operator. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 50 - 4.1.2.2.3.1 Example of Final Operational Notification Date: [ ] Our Ref: [ ] Your Ref: [ ] System Operator address For the Attention of [ ] address Libya Company Secretary [ ] [ ] [ ] [ ] Tel No: ########### [ ] Fax No: ########### Mobile: ########### #######@System Operator.com Dear Sirs [ ] at [ ] Power Station - Final Operational Notification EFFECTIVE FROM [xxx] Libya SYSTEM OPERATOR and [party] are parties to a [Bilateral Connection Agreement]/[Bilateral Embedded Generator Agreement]/[Bilateral Embedded Large Licence Exemptable Agreement] (the “Bilateral agreement”) and [Construction Agreement (the “Construction Agreement”)] dated [ ] providing for [connection to and use] / [use] of the National Electricity Transmission/Distribution System at [connection site] [site of connection]. On [date] SYSTEM OPERATOR issued an Interim Operational Notification ("ION") in respect of [ ] Power Station which has subsequently been extended to remain in force until [date] (the “Term”). The unresolved issues associated with the ION were set out in the ‘Schedule of Unresolved Compliance Issues’ attached to the letter dated [ ]. The ION was issued subject to the condi- tion that significant progress be made towards the resolution of the unresolved issues and on comple- tion of the Term SYSTEM OPERATOR would decide whether to issue a further ION for a fixed period or a Final Operational Notification (“FON”). SYSTEM OPERATOR is pleased to confirm that these issues have now progressed to the point where an FON for [ ] Power Station can be issued with effect from this [ ]. In taking this step SYSTEM OPERATOR is relying upon your continued co-operation with providing plant perfor- mance data as and when system frequency deviations occur. Terms defined in the Connection Code, Bilateral Agreement, Construction Agreement and Grid Code have the same meaning in this letter. I should like to take this opportunity to wish every success to your Power Station in its future opera- tion. Should you require any further information regarding this matter please contact [Connection Agree- ment Manager] on telephone ###########. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 51 - 4.1.2.2.4 Limited Operational Notification (LON) for Type D Power Generating Modules 1. Power Generating Facility Owners to whom a Final Operational Notification (FON) has been granted shall inform the System Operator immediately in the following circumstances: a) it is temporarily subject to either a significant modification or loss of capability, due to imple- mentation of one or more modifications of significance to its performance; or b) in case of equipment failures leading to non-compliance with some relevant requirements. 2. The Power Generating Facility Owner shall apply to the System Operator for a Limited Operational Notification (LON), if the Power Generating Facility Owner reasonably expects the circumstances according to Chapter 4.1.2.2.3.1(1) to persist for more than three months. 3. A Limited Operational Notification (LON) shall be issued by the System Operator with a clear iden- tification of: a) the unresolved issues justifying the granting of the Limited Operational Notification (LON); b) the responsibilities and timescales for expected solution; and c) a maximum period of validity which shall not exceed twelve months. The initial period granted may be shorter, with possibility for extension, if evidence to the satisfaction of the System Op- erator has been made, which demonstrates that substantial progress has been made in terms of achieving full compliance. 4. The Final Operational Notification (FON) shall be suspended during the period of validity of the Limited Operational Notification (LON) with regard to the subjects for which the Limited Operation- al Notification (LON) has been issued. 5. A further prolongation of the period of validity of the Limited Operational Notification (LON) may be granted upon request for derogation made to the System Operator, before the expiry of that peri- od. 6. The System Operator shall have the right to refuse the operation of the Power Generating Module, if the Limited Operational Notification (LON) terminates without removal of the circumstances which caused its issuing. In such a case the Final Operational Notification (FON) shall automati- cally be invalid. 4.2 Operational Notification Procedure for Existing Power Gener- ating Modules 1. In order to assess the advantages of the applicability of any requirement set forth in this Connec- tion Code to Existing Power Generating Modules, the System Operator shall initiate the process referred to in Chapter 3.1(2) by a preparatory stage aimed at identifying cases of merit with the phases defined in Chapter 4.2(2) to (8) below. This preparatory stage shall consist of a qualitative comparison of costs and benefits related to the requirement under consideration for application to Existing Power Generating Modules taking into account network-based or market-based alterna- tives, where applicable. If the System Operator deems the cost of applying the requirement to be Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 52 - low and the benefit to be high then the case can proceed as defined below. If however, the cost is deemed high and or the benefit is deemed low then the System Operator may not proceed further. 2. The System Operator shall carry out a quantitative Cost-Benefit Analysis of a requirement under consideration for application to Existing Power Generating Modules that has demonstrated poten- tial benefits as a result of the preparatory stage according to Chapter 4.2(1) above. This Cost- Benefit Analysis shall be followed by a public consultation. The public consultation shall include, amongst others, a proposal for a transition period for applying a requirement to Existing Power Generating Modules. Such a transition period should not exceed two years from the decision of the Authority on the applicability. 3. Power Generating Facility Owners, DSOs and CDSOs shall assist and contribute to this Cost- Benefit Analysis and provide the relevant data as requested by the System Operator within three months after reception of the request, unless agreed otherwise. 4. The Cost-Benefit Analysis shall be undertaken using one or more of the following calculating prin- ciples: net present value; return on investment; rate of return; and time to break-even. The quantified benefits shall include any marginal socio-economic benefits in terms of improve- ment of security of supply including, but not limited to: associated reduction in probability of loss of supply over the lifetime of the modification; the probable extent and duration of such loss of supply; the societal cost per hour of such loss of supply; as well as benefits to the internal market in electricity, cross-border trade and integration of re- newable energies including, but not limited to: Frequency response; reserve holding; Reactive Power provision; congestion management; and defence measures. The quantified costs shall include as appropriate, but are not limited to: - costs for implementing the requirement; - any attributable loss of opportunity; and/or - change in maintenance and operating costs. 5. If the socio-economic benefits outweigh the costs of applying the requirement under considera- tion to Existing Power Generating Modules, the System Operator shall summarise the analysis within three months in a report which shall include a recommendation on how to proceed. This report shall be subject to public consultation. If, taking due account of the outcome of the public consultation, the System Operator decides to proceed with the issue, the report including such consultation outcome and a proposal on the applicability of the requirement under consideration Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 53 - to Existing Power Generating Modules, shall be forwarded to the Authority within six months for decision. 6. The proposal by the System Operator to the Authority on applicability of any requirement of this Connection Code according to Chapter 3.1(2) to Existing Power Generating Modules according to Chapter 3.1(2) shall include the following: a) an operational notification procedure in order to demonstrate the implementation of the re- quirements by the Power Generating Facility Owner; b) an appropriate transition period for implementing the requirements. The determination of the transition period shall take into account the category of the Power Generating Module accord- ing to Chapter 3.1(6) (a) to (e) and any underlying obstacles for efficient undertaking of the equipment modification/refitting. The Authority shall decide on the case within three months after receipt of the report and the rec- ommendation of the System Operator. The decision of the System Operator on how to proceed with the issue and the decision of the Authority, if any, shall be published. 7. All relevant clauses in contracts and/or relevant clauses in general terms and conditions relating to the grid connection of Existing Power Generating Modules shall be amended to achieve com- pliance with the requirements of this Connection Code, that shall apply to them according to Chapter 4.2(6). The relevant clauses shall be amended within three years after the decision of the Authority on the applicability according to Chapter 3.1(2). This requirement for amendment shall apply regardless of whether the relevant contracts or general terms and conditions provide for such an amendment. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 54 - 5. Compliance 5.1 Compliance Monitoring 5.1.1 Responsibility of the Power Generating Facility Owner 1. The Power Generating Facility Owner shall ensure that a Power Generating Module is compliant with the requirements under this Connection Code. This compliance shall be maintained through- out the lifetime of the facility. 2. Planned modifications of the technical capabilities of the Power Generating Module with possible impact on its compliance to the requirements under this Connection Code shall be notified to the System Operator by the Power Generating Facility Owner before initiating such modification. 3. Any operational incidents or failures of a Power Generating Module that have impact on its com- pliance to the requirements of this Connection Code shall be notified to the System Operator by the Power Generating Facility Owner as soon as possible without any delay after the occurrence of such an incident. 4. Any foreseen test schedules and procedures to verify compliance of a Power Generating Module with the requirements of this Connection Code shall be notified to the System Operator by the Power Generating Facility Owner in due time and prior to their launch and shall be approved by the System Operator. 5. The System Operator shall be invited to participate in such tests and may record the performance of the Power Generating Modules. 5.1.2 Tasks of the System Operator 1. The System Operator shall regularly assess the compliance of a Power Generating Module with the requirements under this Connection Code throughout the lifetime of the Power Generating Fa- cility. The Power Generating Facility Owner shall be informed of the outcome of this assessment. 2. The System Operator shall have the right to request that the Power Generating Facility Owner carries out compliance tests and simulations not only during the operational notification proce- dures according to Chapter 4, but repeatedly throughout the lifetime of the Power Generating Fa- cility according to a plan or general scheme for repeated tests and simulations defined or after any failure, modification or replacement of any equipment that may have impact on the Power Gener- ating Module’s compliance with the requirements under this Connection Code. The Power Gener- ating Facility Owner shall be informed of the outcome of these compliance tests and simulations. 3. The System Operator shall make publicly available the list of information and documents to be provided as well as the requirements to be fulfilled by the Power Generating Facility Owner in the frame of the compliance process. Such list shall, notably, cover the following information, docu- ments and requirements: a) all documentation and certificates to be provided by the Power Generating Facility Owner; Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 55 - b) details of the technical data of the Power Generating Module with relevance to the grid con- nection; c) requirements for models for steady-state and dynamic system studies; d) timely provision of system data required to perform the studies; e) studies by the Power Generating Facility Owner for demonstrating expected steady-state and dynamic performance referring to the requirements set forth in Chapters 5.4 and 5.5 of this Connection Code; and f) conditions and procedures including the scope for registering Equipment Certificates; g) conditions and procedures for use of relevant Equipment Certificates issued by an authorised certifier by the Power Generating Facility Owner instead of part of the activity for compliance as described in this Connection Code. 4. The System Operator shall make publicly available the allocation of responsibilities to the Power Generating Facility Owner and to the Network Operator for compliance testing, simulation and monitoring. 5. The System Operator may partially or totally assign the performance of its compliance monitoring to third parties. In this case, the System Operator shall ensure compliance by appropriate confi- dentiality commitments with the assignee. 6. The System Operator shall not withhold unreasonably any operational notification as per Chapter 4, if compliance tests or simulations cannot be performed as agreed between the System Opera- tor and the Power Generating Facility Owner due to reasons which are in the sole control of the System Operator. 5.1.3 Common Provisions on Compliance Testing 1. The testing of the performance of the individual Power Generating Modules within the Power Generating Facility shall aim at demonstrating the fulfilment of the requirements of this Connection Code. 2. The Power Generating Facility Owner shall use its best efforts to provide the System Operator on an ongoing basis with relevant information regarding its programme for testing the Power Generat- ing Facility prior to the Commercial Operation Date. Not less than 45 days prior to the com- mencement of such test programme, the Power Generating Facility Owner shall deliver to the Sys- tem Operator in writing the final draft programme for testing the Power Generating Facility. The System Operator shall within 14 days of delivery of the final draft programme give comments to the Power Generating Facility Owner on the final draft programme where after the Power Generat- ing Facility Owner shall prepare and deliver to the System Operator in writing the final programme for testing the Power Generating Facility. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 56 - 3. Commissioning procedure: a) The Power Generating Facility Owner shall give to the System Operator at 60 days advance written notice of the date on which it intends to synchronise the first Power Generating Module (the “First Unit Commissioning Date”) to the Power System and each other Power Generating Module thereafter. b) The Power Generating Facility Owner shall declare a Power Generating Module to be ready for synchronisation with the Power System when: 1) it has been installed in accordance with the required technical specifications and Prudent Utility Practices; 2) it meets all requirements prescribed in the Connection Code or any other Laws of Libya for such synchronisation to the Power System; and 3) it is capable of being operated safely and the Power Generating Facility Owner has ob- tained a certification of the Engineer for energising. c) The Power Generating Facility Owner shall notify the System Operator as soon as the re- quirements of Clause defined by System Operator have been met and the Power Generating Module is ready to be synchronised to the Power System in accordance with the Agreement. d) The System Operator shall inspect any Power Generating Module which the Power Generat- ing Facility Owner intends to synchronise to the Power System within 5 days after being noti- fied in writing by the Power Generating Facility Owner to determine whether the requirements of Clause defined by System Operator have been met. e) The Power Generating Facility Owner shall provide the System Operator with such access to the Power Generating Facility as is reasonably required to make the determinations required under Clause defined by System Operator. f) If the System Operator is satisfied that the Power Generating Module is ready for synchronisa- tion in accordance with the requirements of the Project, it shall within 3 days of the completion of the inspection of the Power Generating Module notify the Power Generating Facility Owner to that effect and provide the Power Generating Facility Owner with all reasonable assistance in synchronising the Power Generating Module and also for conducting the Commissioning Test. g) The Power Generating Facility Owner shall conduct the Commissioning Tests within 15 days from the date of the synchronisation of each Power Generating Module and in the presence of the Engineer and one or more representatives of the System Operator. The Engineer shall submit a certificate of the tested capacity and necessary performance tests of the Power Gen- erating Facility carried out, to each of the Parties. All the Commissioning Tests shall be carried out in accordance with Chapter 5.2 and 5.3 at the expense of the Power Generating Facility Owner. h) The System Operator shall maintain the stability of the frequency, voltage and other electrical properties of the Power System throughout the duration of the tests. In the event of any insta- bility of voltage, frequency or other electrical properties of the Power System during the test, which has an adverse effect on the ability of the Power Generating Facility to operate at its nameplate capacity, the test results shall be corrected for such variations in an agreed man- Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 57 - ner. Alternatively Power Generating Facility Owner shall have the option to reschedule a new test. i) The Power Generating Facility Owner will determine and prepare the testing procedures to be carried out. j) The Power Generating Facility Owner shall give 7 days' notice to the System Operator of any tests to be performed at the Power Generating Facility for purposes of witnessing the tests on- ly. k) The System Operator shall accept into the Power System all the electric energy generated during the tests and shall pay to the Power Generating Facility Owner the amounts specified under Agreement. l) These tests will be coordinated between the Power Generating Facility Owner, System Opera- tor and Authority. The tests schedule will be agreed not less than 120 days prior to the syn- chronisation of each Power Generating Module. 4. Notwithstanding the minimum requirements relating to the compliance testing laid down by the provisions of this Connection Code, the System Operator is entitled to: a) allow the Power Generating Facility Owner to carry out an alternative set of tests, provided that those tests are efficient and sufficient to demonstrate compliance of a Power Generating Module to the requirements under this Connection Code; b) require the Power Generating Facility Owner to carry out an additional or alternative set of tests in case information supplied to the System Operator by the Power Generating Facility Owner in relation to compliance testing under the provisions of Chapter 5.2 or 5.3 of this Con- nection Code are not sufficient to demonstrate compliance to the requirements under this Connection Code; and c) require the Power Generating Facility Owner to carry out appropriate tests in order to demon- strate a Power Generating Module’s performance when operating on alternative fuels or fuel mixes. The System Operator and the Power Generating Facility Owner shall agree on which types of fuel are tested. 5. The Power Generating Facility Owner is responsible for carrying out the tests in accordance with the conditions laid down in Chapters 5.2 and 5.3 of this Connection Code. The System Operator shall make its reasonable efforts to cooperate and not unduly delay the performance of the tests. 6. The Power Generating Facility Owner is responsible for the safety of the personnel and the plant during the tests. 7. The System Operator shall be facilitated to participate to the test either on site or remotely from the Network Operator’s control centre. For that purpose, the Power Generating Facility Owner shall provide suitable monitoring equipment to record all relevant test signals and measurements as well as ensure that the relevant representatives from the Power Generating Facility Owner are available on site for the entire testing period. Signals specified by the System Operator shall be provided, if the System Operator wishes for selected tests to use own equipment to record the performance during tests. The decision as regards the participation of the System Operator to the Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 58 - test and the form of this participation remains at the sole and exclusive discretion of the System Operator. 8. The Power Generating Facility Owner will provide the necessary labour, material, instrumentation and controls to record, observe and evaluate the test data and maintain the logs of all data taken. Where practical the data will be recorded in both hard copy and electronic form. The Power Gen- erating Facility Owner shall specify the variables that will be recorded, the form of recording and the frequency of recording each variable during each test. All instruments and meters will be cali- brated in accordance with Prudent Utility Practices prior to the tests. 9. The Power Generating Facility Owner will provide to the System Operator a test report of the test results and other. The format and contents of the test reports may be modified by mutual agree- ment between the Power Generating Facility Owner and the System Operator in order to meet the test objectives. 5.1.4 Common Provisions on Compliance Simulations 1. The simulation of the performance of the individual Power Generating Modules within the Power Generating Facility shall aim at demonstrating the fulfilment of the requirements of this Connection Code. 2. Notwithstanding the minimum requirements relating to the Compliance Simulations laid down by the provisions of this Connection Code, the System Operator is entitled to: a) allow the Power Generating Facility Owner to carry out an alternative set of simulations, pro- vided that those simulations are efficient and sufficient to demonstrate compliance of a Power Generating Module to the requirements under this Connection Code or national legislation in- cluding national codes; and b) require the Power Generating Facility Owner to carry out an additional or alternative set of simulations in case information supplied to the System Operator by the Power Generating Fa- cility Owner in relation to Compliance Simulation under the provisions of Chapter 5.4 or 5.5 of this Connection Code are not sufficient to demonstrate compliance to the requirements under this Connection Code. 3. The Power Generating Facility Owner shall provide simulation results relevant to each and any in- dividual Power Generating Module within the Power Generating Facility in a report form in order to demonstrate the fulfilment of the requirements of this Connection Code. The Power Generating Facility Owner shall produce and provide a validated simulation model for a Power Generating Module. The coverage of the simulation models is described in Chapter 3.1.3(6) (c). 4. The System Operator shall have the right to check the compliance of the Power Generating Mod- ule with the requirements of this Connection Code by carrying out its own Compliance Simulations based on the provided simulation reports, simulation models and compliance test measurements. 5. The System Operator shall provide to the Power Generating Facility Owner the technical data and the simulation model of the Network, in the extent necessary for carrying out the requested simu- lations according to Chapter 5.4 or 5.5 of this Connection Code. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 59 - 5.2 Compliance Testing for Synchronous Power Generating Modules 5.2.1 Compliance Tests for Type B Synchronous Power Generating Modules 1. Type B Synchronous Power Generating Modules are subject to the following compliance tests. The Equipment Certificates may be used instead of part or all of the tests below if they are provid- ed to the System Operator. 2. Start-Up Test: a) The System Operator shall permit the Power Generating Facility Owner to conduct plant start- up tests at part and full loads including, but not limited to, load rejection tests, performance guarantee tests, reliability tests and capacity tests. 3. Functional Verification Test i.e. Electrical Metering and Relaying: a) The Power Generating Facility Owner shall perform functional verification tests of the protec- tion, control and metering system of the Power Generating Facility as well as the switchyard and network facilities. The purpose of the functional verification tests is to ensure that the power equipment, protection and control system will perform as designed to protect the elec- trical power system in a reliable manner and not jeopardise network facilities. b) The tests shall be conducted to satisfy the System Operator’s requirements. Periodic verific a- tion in accordance with an agreed maintenance schedule shall be performed by the Power Generating Facility Owner as well as the System Operator in a coordinated manner to ensure the integrity of the protection and control system of both facilities. c) The design of the protection, control and metering system shall include adequate test facilities so that functional tests can be properly performed. Tests on relay, meters and control equip- ment shall be in accordance with manufacturer’s recommendations. 4. With regard to the LFSM-O response test: a) The Power Generating Module shall demonstrate its technical capability to continuously modulate Active Power to contribute to Frequency Control in case of large increase of Fre- quency in the system and shall verify the steady-state parameters of regulations, such as Droop and deadband, and dynamic parameters, including Frequency step change response. b) The test shall be carried out by simulating Frequency steps and ramps big enough to activate at least 10 % of Maximum Capacity change in Active Power, taking into account the Droop settings and the deadband. Simulated Frequency deviation signals shall be injected simulta- neously at both the speed and power control loops of the control systems if required, taking in- to account the scheme of these control system. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 60 - c) The test is deemed passed, provided that the following conditions are both fulfilled: 1) the test results, for both dynamic and static parameters, are in line with the requirements as referred to in Chapter 3.1.1(1) (c); and 2) undamped oscillations do not occur after the step change response. 5.2.2 Compliance Tests for Type C Synchronous Power Generating Modules 1. In addition to the compliance tests for Type B Synchronous Power Generating Modules in the conditions as referred to in Chapter 5.2.1, Type C Synchronous Power Generating Modules are subject to the following compliance tests. The Equipment Certificates may be used instead of part or all of the tests below if they are provided to the System Operator. 2. Load Rejection Test: a) The System Operator shall allow the Power Generating Facility Owner to conduct load rejec- tion testing. b) The objective of the load rejection test is to verify that 1) a Power Generating Module does not shut down when shedding 40 %, 75 % and 100 % of the rated load; 2) is capable of continuing operation with its auxiliaries; and 3) is capable of being reloaded in the times specified by its manufacturer. The System Op- erator shall be responsible for any blackout(s) that may occur as a result of the conduct of any tests. 3. Performance Guarantee Tests: a) The objective of the performance guarantee tests is to verify the performance figures of each Power Generating Module and the auxiliary equipment. b) The test shall be carried out generally in accordance with the IEC standards. c) The performance guarantee test shall compose: 1) A predetermined run at 100 % of maximum continuous rating to verify the Power Gener- ating Module net output. 2) Functional tests to demonstrate the performance of all auxiliary equipment in accordance with the manufacturers' guarantees. 4. With regard to the LFSM-U response test: a) The Power Generating Module shall demonstrate its technical capability to continuously modulate Active Power at operating points below Maximum Capacity to contribute to Fre- quency Control in case of large drop of Frequency in the system. b) The test shall be carried out by simulating at appropriate Active Power load points (e.g. 80 %) with low Frequency steps and ramps big enough to activate at least 10 % of Maximum Ca- pacity Active Power change, taking into account the Droop settings and the deadband. Simu- lated Frequency deviation signals shall be injected simultaneously into both the speed gover- Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 61 - nor and the load controller references if required, taking into account the speed governor and the load controller scheme. c) The test is deemed passed, provided that the following conditions are both fulfilled: 1) the test results, for both dynamic and static parameters, are in line with the requirements as referred to in Chapter 3.1.3(2) (b); and 2) undamped oscillations do not occur after the step change response. 5. With regard to the FSM response test: a) The Power Generating Module shall demonstrate its technical capability to continuously modulate Active Power over the full operating range between Maximum Capacity and Mini- mum Regulating Level to contribute to Frequency Control and shall verify the steady-state pa- rameters of regulations, such as Droop and deadband and dynamic parameters, including ro- bustness through Frequency step change response and large, fast Frequency changes. b) The test shall be carried out by simulating Frequency steps and ramps big enough to activate the whole Active Power Frequency response range, taking into account the Droop settings, the deadband and the Real Power headroom or deload (margin to Maximum Capacity in op- erational timescale). Simulated Frequency deviation signals shall be injected simultaneously into the references of both the speed governor and the load controller of the unit or plant con- trol system if required, taking into account the speed governor and load controller scheme. c) The test is deemed to be passed, provided that the following conditions are all fulfilled: 1) activation time of full Active Power Frequency response range as result of a step Fre- quency change has been no longer than required by Chapter 3.1.3(2) (c); 2) undamped oscillations do not occur after the step change response; 3) the initial delay time has been according to Chapter 3.1.3(2) (c); 4) the Droop settings are available within the range defined in Chapter 3.1.3(2) (c) and deadband (thresholds) is not more than the value in Chapter 3.1.3(2) (c); and 5) insensitivity of Active Power Frequency response at any relevant operating point does not exceed the requirements set forth in Chapter 3.1.3(2) (c). 6. With regard to the frequency restoration control test: a) The Power Generating Module shall demonstrate its technical capability to participate in Fre- quency restoration control. The cooperation of FSM and Frequency restoration control shall be checked. b) The test is deemed passed, provided that the test results, for both dynamic and static parame- ters, are in line with the requirements as referred to in Chapter 3.1.3(2) (d). c) With regard to the Black Start Capability test: 1) Power Generating Modules with Black Start Capability in accordance with Chapter 3.1.3(5) (a), shall demonstrate this technical capability to start from shut down without any external energy supply. 2) The test is deemed passed, provided that the start-up time has been not longer than the timeframe according to Chapter 3.1.3(5) (a) point 2). Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 62 - 7. With regard to the tripping to house load test: a) Power Generating Modules shall demonstrate their technical capability to trip to and stably operate on house load. b) The test shall be carried out at the Maximum Capacity and nominal Reactive Power of the Power Generating Module before load shedding. c) Further conditions for this test shall be defined by the System Operator taking into account Chapter 3.1.3(5) (c). d) The test is deemed passed, provided that tripping to house load has been successful and sta- ble House load Operation has been demonstrated for time period according to Chapter 3.1.3(5) (c) and re-synchronisation to the Network has been performed successfully. 8. With regard to the Reactive Power Capability test: a) The Power Generating Module shall demonstrate its technical capability to provide leading and lagging Reactive Power capability according to 3.2.2(2) (b) and (c). b) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the Power Generating Module has been operating no shorter than 1 hour at maximum Reactive Power, both leading and lagging, for each of: – Minimum Stable Operating Level; – Maximum Capacity; and – an Active Power operating point between those maximum and minimum ranges; 2) the Power Generating Module demonstrates its capability to change to any Reactive Power target value within the agreed or decided Reactive Power range within the speci- fied performance targets of the relevant Reactive Power control scheme. 5.2.3 Compliance Tests for Type D Synchronous Power Generating Modules 1. Type D Synchronous Power Generating Modules are subject to the compliance tests for Type B and C Synchronous Power Generating Modules in the conditions as referred to in Chapters 5.2.1 and 5.2.2. The Equipment Certificate may be used instead of part or all of the tests below, if they are provided to the System Operator. 5.3 Compliance Testing for Power Park Modules 5.3.1 Compliance Tests for Type B Power Park Modules 1. The Equipment Certificate may be used instead of part or all of the tests below, if they are provid- ed to the System Operator. 2. With regard to Type B Power Park Modules the LFSM-O response tests shall be carried out re- flecting the choice of control scheme selected by the System Operator. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 63 - a) The Power Park Module shall demonstrate its technical capability to continuously modulate Active Power to contribute to Frequency Control in case of increase of Frequency in the sys- tem and shall verify the steady-state parameters of regulations, such as Droop and deadband, and dynamic parameters, including Frequency step change response. b) The test shall be carried out by simulating Frequency steps and ramps big enough to activate at least 10 % of Maximum Capacity change in Active Power, taking into account the Droop settings and the deadband. Simulated Frequency deviation signals shall be injected to perform this test. c) The test is deemed passed, provided that the test results, for both dynamic and static parame- ters, are in line with the requirements as referred to in 3.1.1(1) (c). 5.3.2 Compliance Tests for Type C Power Park Modules 1. In addition to the compliance tests for Type B Power Park Modules in the conditions as referred to in Chapter 5.3.1, Type C Power Park Modules are subject to the following compliance tests. The Equipment Certificates may be used instead of part or all of the tests below, if they are provided to the System Operator. 2. With regard to the Active Power controllability and control range test: a) The Power Park Module shall demonstrate its technical capability to operate at a load level no higher than the Setpoint set by the System Operator. b) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the load level of the Power Park Module is kept below the Setpoint; 2) the Setpoint is implemented according to the requirements as referred to in Chapter 3.1.3(2) (a); and 3) the accuracy of the regulation is compliant with specified value according to Chapter 3.1.3(2) (a). 3. With regard to the LFSM-U response test: a) The Power Park Module shall demonstrate its technical capability to continuously modulate Active Power to contribute to Frequency Control in case of large drop of Frequency in the sys- tem. b) The test shall be carried out by simulating the Frequency steps and ramps big enough to acti- vate at least 10 % of Maximum Capacity Active Power change with a starting point of no more than 80 % of Maximum Capacity, taking into account the Droop settings and the deadband. Simulated Frequency deviation signals shall be injected in the Power Park Module controller scheme, taking into account both speed governor and load controller scheme, if applicable. c) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the test results, for both dynamic and static parameters, are in line with the requirements as referred to in Chapter 3.1.3(2) (b); and 2) undamped oscillations after the step change response do not occur. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 64 - 4. With regard to the FSM response test: a) The Power Park Module shall demonstrate its technical capability to continuously modulate Active Power over the full operating range between Maximum Capacity and Minimum Regulat- ing Level to contribute to Frequency Control and shall verify the steady-state parameters of regulations, such as insensitivity, Droop, deadband and range of regulation, as well as dynam- ic parameters, including Frequency step change response. b) The test shall be carried out by simulating Frequency steps and ramps big enough to activate the whole Active Power Frequency response range, taking into account the Droop settings and the deadband. Simulated Frequency deviation signals shall be injected to perform this test. c) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the activation time of full Active Power Frequency response range as result of a step Fre- quency change has been no longer than that required by Chapter 3.1.3(2) (c); 2) undamped oscillations do not occur after the step change response; 3) the initial delay has been according to Chapter 3.1.3(2) (c); 4) the Droop settings are available within the ranges defined in Chapter 3.1.3(2) (c) and deadband (thresholds) is not more than the value chosen by the System Operator; and 5) the insensitivity of Active Power Frequency response does not exceed the requirement according to Chapter 3.1.3(2) (c). 5. With regard to the frequency restoration control test: a) The Power Park Module shall demonstrate its technical capability to participate in Frequency restoration control. The cooperation of both FSM and Frequency restoration control shall be checked. b) The test is deemed passed, provided that the test results for both dynamic and static parame- ters are in line with the requirements as referred to in Chapter 3.1.3(2) (d). 6. With regard to the Reactive Power capability test: a) The Power Park Module shall demonstrate its technical capability to provide leading and lag- ging Reactive Power capability according to Chapter 3.2.2(3) (b) and (c). b) The Reactive Power Capability test shall be carried out at maximum Reactive Power, both leading and lagging, and concerning the verification of the following parameters: 1) operation in excess of 60 % of Maximum Capacity for 30 min; 2) operation within the range of 30 – 50 % of Maximum Capacity for 30 min; and 3) operation within the range of 10 – 20 % of Maximum Capacity for 60 min. c) The test is deemed passed, provided that the following criteria are cumulatively fulfilled: 1) the Power Park Module has been operating no shorter than requested duration at maxi- mum Reactive Power, both leading and lagging, in each parameter as referred to in Chapter 5.3.2(6) (b); 2) the Power Park Module has demonstrated its capability to change to any Reactive Power target value within the agreed or decided Reactive Power range within the specified per- formance targets of the relevant Reactive Power control scheme; and Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 65 - 3) no action of any protection within the operation limits defined by Reactive Power capacity diagram occurs. 7. With regard to the Voltage Control Mode test: a) The Power Park Module shall demonstrate its capability to operate in Voltage control mode in the conditions set forth in Chapter 3.3.2(3) (d) point 2). b) The Voltage Control Mode test shall apply concerning the verification of the following parame- ters: 1) the implemented Slope and deadband of the static characteristic; 2) the accuracy of the regulation; 3) the insensitivity of the regulation; and 4) the time of Reactive Power activation. c) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the implemented Slope and deadband of the static characteristic; 2) the range of regulation and adjustable the Droop and deadband is compliant with agreed or decided characteristic parameters, according to Chapter 3.3.2(3) (d); 3) the insensitivity of Voltage Control is not higher than 0.01 pu, according to Chapter 3.3.2(3) (d); and 4) following a step change in Voltage, 90 % of the change in Reactive Power output has been achieved within the times and tolerances according to Chapter 3.3.2(3) (d). 8. With regard to the Reactive Power Control Mode test: a) The Power Park Module shall demonstrate its capability to operate in Reactive Power control mode, according to the conditions referred to in Chapter 3.3.2(3) (d) point 3). b) The Reactive Power Control Mode test shall be complementary to the Reactive Power Capa- bility test. c) The Reactive Power Control Mode test shall apply concerning the verification of the following parameters: 1) the Reactive Power Setpoint range and step; 2) the accuracy of the regulation; and 3) the time of Reactive Power activation. d) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the Reactive Power Setpoint range and step is ensured according to Chapter 3.3.2(3) (d); and 2) the accuracy of the regulation is compliant with the conditions as referred to in Chapter 3.3.2(3) (d). 9. With regard to the Power Factor Control Mode test: a) The Power Park Module shall demonstrate its capability to operate in Power Factor control mode according to the conditions referred to in Chapter 3.3.2(3) (d) point 4). b) The Power Factor Control Mode test shall apply concerning the verification of the following pa- rameters: Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 66 - 1) the Power Factor Setpoint range; 2) the accuracy of the regulation; and 3) the response of Reactive Power due to step change of Active Power. c) The test is deemed passed, provided that the following conditions are cumulatively fulfilled: 1) the Power Factor Setpoint range and step is ensured according to Chapter 3.3.2(3) (d); 2) the time of Reactive Power activation as result of step Active Power change does not ex- ceed the requirement according to Chapter 3.3.2(3) (d); and 3) the accuracy of the regulation is compliant with the value, as referred to in Chapter 3.3.2(3) (d). 10. With regard to the tests identified in Chapter 5.3.2(7), (8) and (9) the System Operator may select only one of the three control options for testing. 5.3.3 Compliance Tests for Type D Power Park Modules 1. Type D Power Park Modules are subject to the compliance tests for Type B and C Power Park Modules in the conditions as referred to in Chapters 5.3.1 and 5.3.2. The Equipment Certificates may be used instead of part or all of the tests below, if they are provided to the System Operator. 5.4 Compliance Simulations for Synchronous Power Generating Modules 5.4.1 Compliance Simulations for Type B Synchronous Power Generating Modules 1. The Equipment Certificates may be used instead of part or all of the simulations below, if they are provided to the System Operator. 2. Type B Synchronous Power Generating Modules are subject to the following compliance simula- tions. 3. With regard to the LFSM-O response simulation: a) The Power Generating Module shall demonstrate its capability to simulate Active Power modulation at high Frequency according to Chapter 3.1.1(1) b. b) The simulation shall be carried out by simulating high Frequency steps and ramps reaching Minimum Regulating Level, taking into account the Droop settings and the deadband. c) The simulation is deemed passed, provided that: 1) the simulation model of the Power Generating Module is validated against the compliance test for LFSM-O response as referred to in Chapter 5.2.1(2); and 2) compliance with the requirement according to Chapter 3.1.1 (1) (c) is demonstrated. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 67 - 4. With regard to the Type B fault-ride-through capability of Synchronous Power Generating Modules simulation: a) The Power Generating Module shall demonstrate its capability to simulate fault-ride-through capability in the conditions set forth in Chapter 3.1.2(3) (a). b) The simulation is deemed passed, provided that compliance with the requirement according to Chapter 3.1.2(3) (a) is demonstrated. 5. With regard to the Post Fault Power Active Recovery simulation: a) The Power Generating Module shall demonstrate its capability to simulate post fault Active Power recovery in the conditions set forth in Chapter 3.2.1(3) (a). b) The simulation is deemed passed, provided that compliance with the requirement according to Chapter 3.2.1(3) (a) is demonstrated. 5.4.2 Compliance Simulations for Type C Synchronous Power Generating Modules 1. In addition to the Compliance Simulations for Type B Synchronous Power Generating Modules in the conditions as referred to in Chapter 5.4.1, Type C Synchronous Power Generating Modules are subject to the following Compliance Simulations. The Equipment Certificates may be used in- stead of part or all of the simulations below, if they are provided to the System Operator. 2. With regard to the LFSM-U response simulation: a) The Power Generating Module shall demonstrate its capability to simulate Active Power modulation at low Frequencies according to Chapter 3.1.3(2) b. b) The simulation shall be carried out by simulating low Frequency steps and ramps reaching Maximum Capacity, taking into account the Droop settings and the deadband. c) The simulation is deemed passed, provided that: 1) the simulation model of the Power Generating Module is validated against the compliance test for LFSM-U response as referred to in Chapter 5.2.2(2); and 2) compliance with the requirement according to Chapter 3.1.3(2) (b) is demonstrated. 3. With regard to the FSM response simulation: a) The Power Generating Module shall demonstrate its capability to modulate Active Power over the full Frequency range according to Chapter 3.1.3(2) (c). b) The simulation shall be carried out by simulating Frequency steps and ramps big enough to activate the whole Active Power Frequency response range, taking into account the Droop settings and the deadband. c) The simulation is deemed passed, provided that: 1) the simulation model of the Power Generating Module is validated against the compliance test for LFSM-U response as referred to in Chapter 5.2.2(3); and Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 68 - 2) compliance with the requirement according to Chapter 3.1.3(2) (c) is demonstrated. 4. With regard to the Island Operation simulation: a) The Power Generating Module shall demonstrate its performance during Island Operation in the conditions as referred to in Chapter 3.1.3(5) (b). b) The simulation is deemed passed, provided that the Power Generating Module reduces or in- creases the Active Power output from its previous operating point to any new operating point within the P-Q-Capability Diagram within the limits of Chapter 3.1.3(5) (b) without disconnec- tion of the Power Generating Module from the island due to over-/underfrequency. 5. With regard to the Reactive Power Capability simulation: a) The Power Generating Module shall demonstrate its capability to simulate leading and lagging Reactive Power capability in the conditions referred to in Chapter 3.2.2(2) (b) and (c). b) The simulation is deemed passed, provided that the following conditions are cumulatively ful- filled: 1) the simulation model of the Power Generating Module is validated against the compliance tests for Reactive Power Capability as referred to in Chapter 5.2.2(7); and 2) compliance with the requirements as referred to in Chapter 3.2.2(2) (b) and (c) is demon- strated. 5.4.3 Compliance Simulations for Type D Synchronous Power Generating Modules 1. In addition to the Compliance Simulations for Type B and C Synchronous Power Generating Modules in the conditions as referred to in Chapters 5.4.2 and 5.4.3, except for the Type B fault- ride-through capability of Synchronous Power Generating Modules as referred to in Chapter 5.4.1(4), Type D Synchronous Power Generating Modules are subject to the following Compliance Simulations. The Equipment Certificates may be used instead of part or all of the simulations be- low, if they are provided to the System Operator. 2. With regard to the Power Oscillations Damping Control simulation: a) The Power Generating Module shall demonstrate the performance of its control system (PSS function) to damp power oscillations in the conditions set forth in Chapter 3.2.3(2) (a). b) The tuning shall result in improved damping of corresponding Active Power response of the AVR in combination with the PSS function compared to the Active Power response of the AVR alone. c) The simulation is deemed passed, provided that the following conditions are cumulatively ful- filled: 1) the PSS function damps the existing power oscillations of the Power Generating Module within a Frequency range specified by the System Operator. This Frequency range shall include the local mode frequency of the Power Generating Module and the expected Network oscillations; and Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 69 - 2) a sudden load reduction of the Power Generating Module from 1 p.u. to 0.6 p.u. of the Maximum Capacity has not lead to undamped oscillations in Active or Reactive Power of the Power Generating Module. 3. With regard to the Type D fault-ride-through capability of Synchronous Power Generating Modules simulation: a) The Power Generating Module shall demonstrate its capability to simulate fault-ride-through capability in the conditions set forth in Chapter 3.1.4(3) (a). b) The simulation is deemed passed, provided that compliance with the requirement according to Chapter 3.1.4(3) (a) is demonstrated. 5.5 Compliance Simulations for Power Park Modules 5.5.1 Compliance Simulations for Type B Power Park Modules 1. Type B Power Park Modules are subject to the following compliance simulations. The Equipment Certificates may be used instead of part or all of the simulations below, if they are provided to the System Operator. 2. With regard to the LFSM-O response simulation: a) The Power Park Module shall demonstrate its capability to simulate Active Power modulation at high Frequency according to Chapter 3.1.1(1) b. b) The simulation shall be carried out by simulating high Frequency steps and ramps reaching Minimum Regulating Level, taking into account the Droop settings and the deadband. c) The simulation is deemed passed, provided that: 1) the simulation model of the Power Park Module is validated against the compliance test for LFSM-O response as referred to in Chapter 5.3.1(2); and 2) compliance with the requirement according to Chapter 3.1.1(1) (c) is demonstrated. 3. With regard to the fast acting additional reactive Current injection simulation: a) The Power Generating Module shall demonstrate its capability to simulate fast acting addi- tional reactive Current injection in the conditions set forth in Chapter 3.3.1(2) (b). b) The simulation is deemed passed, provided that compliance with the requirement according to Chapter 3.3.1(2) (b) is demonstrated. 4. With regard to the Type B fault-ride-through capability of Power Park Modules simulation: a) The Power Generating Module shall demonstrate its capability to simulate fault-ride-through capability in the conditions set forth in Chapter 3.1.2(3) (a). b) The simulation is deemed passed, provided that compliance with the requirement according to Chapter 3.1.2 (3) (a) is demonstrated. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 70 - 5. With regard to the Post Fault Power Active Recovery simulation: a) The Power Generating Module shall demonstrate its capability to simulate post fault Active Power recovery in the conditions set forth in Chapter 3.3.1(3) (a). b) The simulation is deemed passed, provided that compliance with the requirement according to Chapter 3.3.1(3) (a) is demonstrated. 5.5.2 Compliance Simulations for Type C Power Park Modules 1. In addition to the Compliance Simulations for Type B Power Park Modules in the conditions as re- ferred to in Chapter 5.5.1, Type C Power Park Modules are subject to the following Compliance Simulations. The Equipment Certificates may be used instead of part or all of the simulations be- low, if they are provided to the System Operator. 2. With regard to the LFSM-U response simulation: a) The Power Park Module shall demonstrate its capability to simulate Active Power modulation at low Frequencies according to Chapter 3.1.3(2) b. b) The simulation shall be carried out by simulating low Frequency steps and ramps reaching Maximum Capacity, taking into account the Droop settings and the deadband. c) The simulation is deemed passed, provided that: 1) the simulation model of the Power Park Module is validated against the compliance test for LFSM-U response as referred to in Chapter 5.3.2(3); and 2) compliance with the requirement according to Chapter 3.1.3(2) (b) is demonstrated. 3. With regard to the FSM response simulation: a) The Power Park Module shall demonstrate its capability to modulate Active Power over the full Frequency range according to Chapter 3.1.3(2) (c). b) The simulation shall be carried out by simulating Frequency steps and ramps big enough to activate the whole Active Power Frequency response range, taking into account the Droop settings and the deadband. c) The simulation is deemed passed, provided that: 1) the simulation model of the Power Park Module is validated against the compliance test for LFSM-U response as referred to in Chapter 5.3.2(4); and 2) compliance with the requirement according to Chapter 3.1.3(2) (c) is demonstrated. 4. With regard to the Island Operation simulation: a) The Power Generating Module shall demonstrate its performance during Island Operation in the conditions as referred to in Chapter 3.1.3(5) (b). b) The simulation is deemed passed, provided that the Power Generating Module reduces or in- creases the Active Power output from its previous operating point to any new operating point Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 71 - within the P-Q-Capability Diagram within the limits of Chapter 3.1.3(5) (b) without disconnec- tion of the Power Generating Module from the island due to over-/underfrequency. 5. With regard to the simulation of the capability of providing Synthetic Inertia: a) The model of the Power Generating Module shall demonstrate its capability to simulate the capability of providing Synthetic Inertia to a low Frequency event in the conditions as referred to in Chapter 3.3.2(2) (a). b) The simulation is deemed passed, provided that the model demonstrates compliance with the conditions of Chapter 3.3.2(2) (a). 6. With regard to the Reactive Power capability simulation: a) The Power Park Module shall demonstrate its capability to simulate leading and lagging Reac- tive Power capability in the conditions referred to in Chapter 3.3.2(3) (b) and (c). b) The simulation is deemed passed, provided that the following conditions are cumulatively ful- filled: 1) the simulation model of the Power Park Module is validated against the compliance tests for Reactive Power Capability as referred to in Chapter 5.3.2(6); and 2) compliance with the requirements as referred to in Chapter 3.3.2(3) (b) and (c) is demon- strated. 7. With regard to the power oscillations damping control simulation: a) The model of the Power Generating Module shall demonstrate its capability to simulate power oscillations damping capability in the conditions as referred to in Chapter 3.3.2(3) (f). b) The simulation is deemed passed, provided that the model demonstrates compliance with the conditions of Chapter 3.3.2(3) (f). 5.5.3 Compliance Simulations for Type D Power Park Modules 1. In addition to the Compliance Simulations for Type B and C Power Park Modules in the conditions as referred to in Chapters 5.5.2 and 5.5.3, except for the Type B fault-ride-through capability of Power Park Modules as referred to in Chapter 5.5.1(4), Type D Power Park Modules are subject to the Type D fault-ride-through capability of Power Park Modules Compliance Simulation. The Equipment Certificates may be used instead of part or all of the simulations below, if they are pro- vided to the System Operator. 2. The model of the Power Generating Module shall demonstrate its capability to simulate fault-ride- through capability in the conditions as referred to in Chapter 3.1.4(3) (a). 3. The simulation is deemed passed, provided that the model demonstrates compliance with the conditions of Chapter 3.1.4(3) (a) respectively. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 72 - 6. Power Quality 6.1 Harmonics 1. The 95 % weekly value of EIhi, the r.m.s. value of individual current harmonics over "short" 10 min periods, shall not exceed the emission limits at the PCC. The System Operator defines for each Power Generating Module current harmonic emission limits being derived from the voltage har- monic planning levels given in Table 6-1 in accordance with IEC/TR 61000-3-6 while the compati- bility levels for individual harmonic voltages in power systems up to 33 kV are given in Table 6-4. Table 6-1: Planning levels for harmonic voltages (in percent of the fundamental voltage) for system rated voltages above 1 kV Odd harmonics Odd harmonics Even harmonics non-multiple of 3 multiple of 3 Harmonic voltage Har- Harmonic voltage Harmonic voltage Harmonic Harmonic % monic % % order order HV, order HV, h MV MV h MV HV, EHV EHV h EHV 5 5 2 3 4 2 2 1.8 1.4 7 4 2 9 1.2 1 4 1 0.8 11 3 1.5 15 0.3 0.3 6 0.5 0.4 13 2.5 1.5 21 0.2 0.2 8 0.5 0.4 1.9*17/h 0.25*10/h 0.19*10/h 17≤h≤49 1.2*17/h 21≤h≤45 0.2 0.2 10≤h≤50 -0.2 +0.22 +0.16 The planning levels for the total harmonic distortion are THD≤33 kV = 6.5 % and THD>33 kV = 3 %. Table 6-2: Compatibility levels for individual harmonic voltages in power systems up to 33 kV Odd harmonics Odd harmonics Even harmonics non-multiple of 3 multiple of 3 Harmonic Harmonic Harmonic Harmonic Harmonic Harmonic order voltage order voltage order voltage h % h % h % 5 6 3 5 2 2 7 5 9 1.5 4 1 11 3.5 15 0.4 6 0.5 13 3 21 0.3 8 0.5 17≤h≤49 2.27*17/h-0.27 21≤h≤45 0.2 10≤h≤50 0.25*10/h+0.25 The compatibility level for the total harmonic distortion is THD = 8 % Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 73 - 6.2 Voltage Variation 6.2.1 Voltage Fluctuation 1. The 95 % weekly value of short term flicker (Pst) and long term flicker (Plt), shall not exceed the emission limit at the PCC. The System Operator defines for each Power Generating Module emis- sion limits being derived from the planning levels given in Table 6-3 in accordance with IEC/TR 61000-3-7, while the compatibility levels for flicker in power systems up to 400 V are given in Table 6-4. Table 6-3: Planning levels for flicker for system rated voltages above 1 kV Planning levels MV HV, EHV Pst 0.9 0.8 Plt 0.7 0.6 Table 6-4: Compatibility levels for flicker in voltage systems up to 400 V Compatibility levels Pst 1.0 Plt 0.8 6.2.2 Voltage Unbalance 1. The 95 % weekly value of i2sh, current unbalance emission level over "short" 10 min periods, should not exceed the emission limit at the PCC. The System Operator defines for each Power Generating Module current unbalance emission limit being derived from the voltage unbalance planning levels given in Table 6-1 in accordance with IEC/TR 61000-3-13, while the compatibility level for voltage unbalance in power systems up to 33 kV is given in Table 6-6. Table 6-5: Planning levels for voltage unbalance for system rated voltages above 1 kV Planning level Voltage level Lu2 (%) 11 kV, 33 kV 1.8 66 kV, 132 kV, 220 kV 1.4 400 kV 0.5 Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 74 - Table 6-6: Compatibility levels for voltage unbalance in power systems up to 33 kV Compatibility levels Cu2 (%) 1.0 Note: The negative sequence voltage may vary above 1 %, but not beyond 2 % for a total of 5 minutes in every 30 minute period for Type B Power Generating Modules. 2. A Power Park Module shall ensure that current in each phase of a three-phase electrical installa- tion does not deviate from the average of the three-phase currents: a. by more than 5 % for a standard nominal voltage up to 1 kV; and b. by more than 2 % for a standard nominal voltage above 1 kV. 3. Notwithstanding clause in Chapter 6.2 Voltage Fluctuation, deviations are permissible for periods of less than 2 minutes: a. Up to 10 % for a standard nominal voltage up to 1 kV; and b. Up to 4 % for a standard nominal voltage above 1 kV. 6.3 Frequency Variation 1. The nominal frequency of the supply voltage shall be 50 Hz. Under normal operating conditions the mean value of the fundamental frequency measured over 10 s shall be within a range of: – for systems with synchronous connection to SYSTEM OPERATOR network 50 Hz ± 1 % (i.e. 49.5 ... 50.5 Hz) during 99.5 % of a year, 50 Hz + 4 %/- 6 % (i.e. 47 ... 52 Hz) during 100 % of the time. – for systems with no synchronous connection to SYSTEM OPERATOR network (e.g. supply systems on certain islands) 50 Hz ± 2 % (i.e. 49 ... 51 Hz) during 95 % of a week, 50 Hz ± 15 % (i.e. 42.5 ... 57.5 Hz) during 100 % of the time. 6.4 Measuring the Quality of Delivered Electric Power 1. Measuring the quality of delivered electric power at the Interconnection Points shall be carried out in accordance with the standard IEC 61000-4-30, by measuring phase voltages and line currents. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 75 - 7. Non-Compliance 7.1 Derogations 1. The procedure for derogation defined in this Chapter applies to all Power Generating Facility Owners, both of Existing and New Power Generating Modules, to which the provisions of this Connection Code are applicable pursuant to Chapter 3. Only the Power Generating Facility Owner shall have the right to apply for derogations for Power Generating Modules within its facility. 2. It shall apply as well to the System Operator when applying for derogations for classes of both ex- isting and new Power Generating Modules connected to the Network. 3. The derogation process shall be transparent, non-discriminatory, non-biased, well documented and based in particular on the Cost-Benefit Analysis performed, in the conditions set forth by Chapter 4.2(4) and (5), by the System Operator. Cost-Benefit Analysis does not need to be per- formed by the System Operator if, on its reasoned request, an individual exemption is granted to the System Operator by the Authority. 4. Criteria for assessing the request for derogation shall be set by the Authority taking into account recommendation of the System Operator. The criteria set by the Authority shall be non- discriminatory, objective and shall be published by the Authority. 7.1.1 Request for Derogation 1. Power Generating Facility Owners may apply for derogation in respect of one or more require- ments of this Connection Code by submitting a request to the System Operator. 2. The request for derogation, submitted by the Power Generating Facility Owner shall include all the information and documents which are required by the System Operator, including, inter alia, but not limited to: a) identifying data of the Power Generating Facility Owner, with reference contact person for any communications; b) the specific Power Generating Module, to which the request is referred to; c) the provision of the Connection Code, for which a derogation is requested, with the detailed description of the requested derogation; and d) detailed reasoning accompanied with all relevant documents supporting the request. 3. A DSO or CDSO may apply for derogation in respect of one or more requirements of this Connec- tion Code by submitting a request to the System Operator. 4. The request for derogation, submitted by the DSO or CDSO shall include all the information and documents, which are required by the System Operator, including, inter alia, but not limited to: a) identifying data of the DSO or CDSO, with reference contact person for any communications; b) the number of Power Generating Modules affected and the total installed capacity, to which the request is referred to; Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 76 - c) the provision of the Connection Code, for which a derogation is requested, with the detailed description of the requested derogation; and d) detailed reasoning accompanied with all relevant documents supporting the request. 5. The System Operator may apply for derogation in respect of one or more requirements of this Connection Code by submitting a request to the National Regulatory Authority. 6. The request for derogation, submitted by the System Operator shall include the following infor- mation: a) identifying data of the System Operator, with reference contact person for any communica- tions; b) the number of Power Generating Modules affected and the total installed capacity, to which the request is referred to; c) the provision of the Connection Code, for which a derogation is requested, with the detailed description of the requested derogation; and d) detailed reasoning accompanied with all relevant documents supporting the request. 7.1.2 Decision on Derogation 1. Further to the request for derogation submitted by the Power Generating Facility Owner, the Sys- tem Operator shall assess the request and related documentation. If the request or the related documentation is considered to be incomplete the Power Generating Facility Owner shall submit the missing information as requested by the System Operator. As from the day of the receipt of the complete request by the System Operator until the issuance of the decision granting or refus- ing the derogation by the Authority according to Chapter 7.1.2(7), the Power Generating Module, to which the request is referred to, is deemed as compliant. 2. No later than six months after the receipt of the complete request according to Chapter 7.1.2(1) the System Operator shall submit its assessment of the request, including a reasoned opinion, to- gether with a related documentation and, where applicable, a Cost-Benefit Analysis to the Authori- ty. The above deadline shall be shortened to three months in case a reasoned request for exemption from Cost-Benefit Analysis is submitted by the System Operator to the National Regulatory Au- thority. In case the request by the Power Generating Facility Owner is for a Type C or D Power Generat- ing Module connected to a distribution Network or closed distribution Network the System Opera- tor shall obtain the assessment within two months after notification and include it in its submission to the Authority. If the System Operator has requested an exemption from Cost-Benefit Analysis the Authority shall decide on granting or refusing the exemption within one month after the receipt of this request. When the request is rejected, the System Operator shall provide a Cost-Benefit Analysis within three months following the decision of the Authority. 3. Further to the request for derogation submitted by a DSO or CDSO, the System Operator shall assess the request and related documentation. If the request or the related documentation is con- sidered to be incomplete the DSO or CDSO shall submit the missing information as requested by Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 77 - the System Operator. As from the day of the receipt of the complete request by the DSO or CDSO until the issuance of the decision granting or refusing the derogation by the Authority according to Chapter 7.1.2(7), the Power Generating Facilities, to which the request is referred to, are deemed as compliant. 4. No later than six months after the receipt of the complete request according to Chapter 7.1.2(3) the System Operator shall submit its assessment of the request, including a reasoned opinion, to- gether with a related documentation and, where applicable, a Cost-Benefit Analysis performed by the DSO or CDSO. The above deadline shall be shortened to three months in case a reasoned request for exemption from Cost-Benefit Analysis is submitted by the DSO or CDSO to the Authority. If the DSO or CDSO has requested an exemption from the Cost-Benefit Analysis Authority shall decide on granting or refusing the exemption within one month after the receipt of this request. If the request is rejected, the DSO or CDSO shall provide a Cost-Benefit Analysis within three months following the decision of the Authority. 5. Further to the request for derogation submitted by the System Operator, the Authority shall assess the request and related documentation. If the request or the related documentation is considered to be incomplete the System Operator shall submit the missing information as requested by the Authority. As from the day of the receipt of the complete request by the System Operator until the issuance of the decision granting or refusing the derogation by the Authority according to Chapter 7.1.2(7), the Power Generating Facilities, to which the request is referred to, are deemed as com- pliant. 6. Together with request according to Chapter 7.1.2(5) the System Operator shall submit either a Cost-Benefit Analysis or a reasoned request for exemption from Cost-Benefit Analysis to the Au- thority. If the System Operator has requested an exemption from Cost-Benefit Analysis the Author- ity shall decide on granting or rejecting this request within one month after the receipt of this re- quest. When the request is rejected, the System Operator shall provide a Cost-Benefit Analysis within three months following the decision of the Authority. 7. The Authority shall issue a motivated decision granting or refusing the derogation and specifying the duration of the derogation, including a reasoned opinion, within a further three months after re- ceipt of the complete documentation. 8. The Authority shall have the right to issue a motivated decision revoking the granted derogation under the conditions and pursuant to the provisions of national law reserving the vested interests of the concerned grid users, in the cases where the prerequisites for granting the derogation no longer exist for reasons attributable to the concerned grid users. 7.1.3 Compliance of Existing Power Generating Modules 1. An Existing Power Generating Module, which is not compliant with a requirement of the Connec- tion Code, that applies to it according to Chapter 3.1, shall apply for derogation from this require- ment according to Chapter 7.1.1 within twelve months from the day the requirement, of which it is not compliant with, becomes applicable. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx - 78 - 2. The System Operator shall have the right to refuse the operation of the Power Generating Module, if the twelve months period terminates without an application for derogation. Libya SPREL – Grid Code for Renewable Sources 2560_LBY_Grid_Code_for_RE_Updated Final.docx
World Bank Group · Working Paper
Libya - Supporting electricity sector reform : task D - strategic plan for renewable energy development : grid code for renewable sources
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