Article 3.1.k of Law 54/1997 of 27 November of the Electrical Sector establishes, among the powers that correspond to the General Administration of the State, to approve by means of a resolution of the Secretary General of Energy, currently Secretary of State for Energy, the market rules and procedures of operation of an instrumental and technical character necessary for the economic and technical management of the system.

For its part, the Royal Decree 2019/1997 of 26 December, for which the electricity production market is organized and regulated, establishes, in Article 31, that the system operator and the National Energy Commission may propose, for approval by the Ministry of Tourism and Trade, the technical and instrumental operating procedures necessary to carry out the appropriate technical management of the system, which will resolve the National Energy Commission.

The additional provision of Royal Decree 485/2009 of 3 April 2009, which regulates the implementation of the supply of last resort in the electricity sector, provides that the proposals for procedures for the technical and instrumental operations referred to in the preceding paragraph shall be accompanied by the report of the representatives of all the system subjects defined in Article 9 of Law 54/1997 of 27 November of the Sector Electrical.

Under the terms of both Directive 2009 /72/EC of 13 July 2009 on common rules for the internal market in electricity and European Regulation (EC) No 714/2009 on conditions for access to the network for the internal market Cross-border trade in electricity, regional initiatives are being developed as a step towards the establishment of an internal electricity market at European level.

Spain is included, together with Portugal and France, in the South West Regional Electricity Initiative, SWE ERI, and work is being carried out focused on the integration of these markets, with the participation of the regulators, system and market operators and the subjects of the three countries.

In 2009, at the initiative of several European market operators, including the Operator of the Iberian Electricity Market, the project PCR (Price Coupling of Regions) was launched with the aim of harmonizing the various European electricity markets through the use of a common matching algorithm.

The Board of Regulators of the Iberian Electricity Market on 28 November 2011 endorsed its commitment to carry out the precise actions so that the Iberian Electricity Market, or MIBEL, is in a willingness to engage with markets in the North West Europe region (North-West Europe, NWE, which groups the markets of France, Belgium, the Netherlands, Germany, Luxembourg, the UK, Norway, Denmark, Sweden and Finland).

Among these actions were the drivers to delay in two hours the closing of the daily market until 12:00 CET, in sync with the closing time of the markets cited. This change also involves adapting the schedule of subsequent markets such as the intra-day market, the adjustment services, and the process of technical restrictions, as well as the programming and nomination processes. Other content and deadlines were also identified for the required regulatory changes as a result in Portugal and Spain, with the initial objective of finalising the process in June 2012, so that implementation in the MIBEL of the Single-appeal algorithm, common to all participating markets, could take place in the second half of 2012, in parallel with its adoption in the NWE region.

Although these deadlines have been dilated, it is maintained by parts of the system operators and market operator of the NWE region, as has been shown in different statements, the objective of proceeding to the market coupling in that area in November 2013.

Likewise, the commitment of the Board of Regulators of the MIBEL to carry out the necessary steps to ensure that the MIBEL is also available to be coupled and, in this context, the General Directorate of Policy Energy and Mines of the Ministry of Industry, Energy and Tourism sent letters to the market operator and the operator of the system in October 2012 by which they were urged to propose the necessary amendments to the Market and System Operation Procedures, respectively, to set the closing time of the daily market at 12h00 CET.

dated December 13, 2012, "Red Electrica de España, S.A." as an operator of the system, the requested proposal was forwarded to the Secretary of State for Energy. The operating procedures sent contain the necessary modifications to adapt to the change of the closing time of the daily market from 10:00 a.m. to 12:00 with the objective to harmonize at European level the hour of closing of the sessions of negotiation of the electricity markets.

The aforementioned proposal was sent to the National Energy Commission for the issuance of a report pursuant to Article 27.3 of the Royal Decree 2019/1997 of 26 December, by which it organizes and regulates the market of production of electrical energy. At its meeting on 18 April 2013, the Council of the Commission approved the CNE's " Report 7/2013 on the proposal to amend the operating procedures P.O.3.1, P.O.3.2, P.O.3.8 and P.O.3.9, in order to consider the change of time. of the closing of the daily market MIBEL at 12h00 CET ".

View Law 54/1997 of 27 November of the Electrical Sector and of Article 31 of Royal Decree 2019/1997 of 26 December on the organisation and regulation of the electricity production market.

View the proposal made by the System Operator of the operating procedures of the System P.O. -3.1 programming of the generation, P.O. -3.2 resolution of technical restrictions, P.O. -3.8 participation of the facilities of production during the pre-operational testing phase of operation in the processes managed by the system operator and P.O. -3.9 hiring and management of additional power reserve to be raised, after consideration of the comments of the representatives of all system subjects.

This Secretary of State, prior to the report of the National Energy Commission, resolves:

First.

The operating procedures of the IP System are approved. -3.1 generation programming, P.O. -3.2 resolution of technical restrictions, P.O. -3.8 participation of production facilities during the testing phase operating pre-operational in the processes managed by the system operator and P.O. -3.9 hiring and reserve management of additional power to be uploaded, which are inserted below.

Second.

A period of testing is established for the adaptation to the new closing time of the daily market that will start on the date that the resolution of the Secretary of State of Energy for which the rules of functioning of the daily and intra-day market for the production of electrical energy and the change in the closing time of the daily market, and ending on 15 October 2013, the effective date of the entry into force of the new closing time of the daily market in accordance with that resolution.

Third.

This resolution shall take effect on the day following that of its publication in the "Official State Gazette".

Fourth.

As of the date on which this resolution takes effect, the procedures for the operation of the IP system are without effect. -3.1 programming of the generation and P.O. -3.2 resolution of technical restrictions approved by the Resolution of 24 July 2012, by the Secretariat of State for Energy, approving the amendment of the procedures for the operation of the Peninsular Electrical System (SEP) P.O. -3.1; P.O. -3.2; P.O. -9 and P.O. -14.4 and the procedures for Operation of the Electrical and Extractive Systems (SEIE) P.O. SEIE-1 P.O. SEIE-2.2; P.O. SEIE-3.1; P.O. SEIE-7.1; P.O. SEIE-7.2; P.O. SEIE-8.2; P.O. SEIE-9 and P.O. SEIE-2.3 for its adaptation to the new electrical regulation, the P.O. -3.8 Participation of production facilities during the pre-operational testing phase functioning in the processes managed by the system operator, approved by Resolution of 19 October 2006, of the General Secretariat of Energy, approving the operation procedure 3.8, Participation of the facilities of the production during the pre-operational testing phase of the processes managed by the Operator of the System, and the IP. -3.9 hiring and management of additional power reserve to be uploaded, Resolution of 24 February 2012, of the Secretariat of State of Energy, for which the procedure of operation of the P.O. -3.9 system: "hiring and management of additional power reserve to be uploaded".

Madrid, 1 August 2013.-The Secretary of State for Energy, Alberto Nadal Belda.

INDEX OF OPERATION PROCEDURES

P. O. -3.1 Generation programming.

P. O. -3.2 Resolution of technical restrictions.

P. O. -3.8 Participation of production facilities during the pre-operational testing phase of operation in the processes managed by the system operator.

P. O. -3.9 Hiring and backup management additional power to upload.

P. O. -3.1 Generation programming

1. Object

The purpose of this procedure is to establish the process of daily programming of the generation from the nominations of programs derived from the execution of bilateral contracts with physical delivery and the offers for the sale and purchase of energy in the daily and intraday market, so as to ensure the coverage of the demand and the security of the system.

The applicable criteria for the definition of the programming units (PU) used in the programming process of the generation and located in the Spanish electricity system are also incorporated in this procedure.

The programming includes the following successive processes:

a) The daily operating base program (PDBF).

b) The Interim Viable Daily Program (PDVP).

c) The secondary throttling reserve allocation.

d) Final schedules after successive intraday market sessions (PHF).

e) The application, if any, of the deviation management process.

f) The operational schedules set in each hour to the end of the programming horizon (P48).

g) The close program (P48REDRE).

2. Scope of application

This procedure applies to the following subjects:

a) System Operator (OS).

b) Market Subjects (SM).

In the content of this operating procedure, unless expressly stated to the contrary, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the subject holders of programming units.

3. Energy programmes, schedules, programming periods and non-working days

Power programs will correspond to MWh values with a maximum of one decimal number.

All schedules and scheduling periods (semi-open temporary intervals defined by their start time and end time) established in this operating procedure are referred to the European Central Time or CET (Central European Time) or CEST (Central European Summer Time).

For the purposes of the programming process established in this operating procedure, it will be business days: Saturdays, Sundays, holidays in the Madrid square, December 24, and December 31.

4. Definitions

4.1 Daily Operating Base Program (PDBF): It is the daily energy program, with breakdown by programming periods, of the different programming units corresponding to sales and energy acquisitions in the Spanish peninsular electrical system. This program is established by the OS from the program resulting from the appeal of the daily market communicated by the OM, and the information of execution of bilateral contracts with physical delivery communicated according to the established in the This operation procedure.

4.2 Provisional Viable Daily Programme (PDVP): It is the daily programme of programming units for energy sales and acquisitions in the Spanish peninsular electricity system, with a breakdown for periods of programming, incorporating the modifications made to the PDBF for the resolution of the restrictions on security of supply and the technical restrictions identified in application of the safety criteria and the modifications required for post-demand rebalancing.

4.3 Secondary Regulatory Reserve Allocation: Secondary Regulatory Reserve Bid Allocation Process performed by the OS on D-1 day to ensure availability on day D of the regulatory reserve secondary to up and down, required for system security reasons.

4.4 Final Schedule Program (PHF): It is the programming established by the OS after each of the successive sessions of the intraday market of programming units corresponding to sales and energy acquisitions in the Spanish peninsular electricity system, as a result of the aggregation of all firm transactions formalised for each programming period as a result of the daily viable programme and the appeal of offers on the intraday market once resolved, where appropriate, the technical restrictions identified and carried out rear rebalance.

4.5 Operating hours (P48): The operational programme of programming units corresponding to sales and energy acquisitions in the Spanish peninsular electricity system that the OS establishes in each period of programming to the end of the daily programming horizon. The operating schedule will incorporate all the program assignments and redispatches applied by the OS until publication, 15 minutes before the start of each hour.

4.6 Restriction by security of supply: A restriction by guarantee of supply to the production that is determined as necessary of those thermal units of production of electrical energy that use sources of indigenous primary energy combustion to ensure the security of supply up to the maximum limit laid down in Article 25 of Law 54/1997 of 27 November, and take into account the possible limitations of the safety programme which, in accordance with the provisions of the operating procedures, they may be required.

For the resolution of these restrictions the mechanisms described in the operating procedures by which the resolution of the supply guarantee restrictions are established shall apply.

4.7 Technical Restriction: It is any circumstance or incident arising from the situation of the production-transport system that, by affecting the conditions of safety, quality and reliability of the established supply (a) Regulation (EC) No No 2014

the European Parliament and of the Council of the European Parliament and of the Council of the European Parliament and of the Council

In particular restrictions may be identified due to:

(a) Failure to comply with security conditions under permanent and/or contingency arrangements, as defined in the operating procedure establishing the operational and security criteria for the operation of the electrical system.

b) Insufficient secondary and/or tertiary regulation reserve.

c) Insufficient additional power reserve to ensure coverage of the expected demand.

d) Insufficient capacity reserve for voltage control in the Transport Network.

e) Insufficient capacity reservation for service replenishment.

For the resolution of these restrictions the mechanisms described in the operating procedures by which the resolution of the technical restrictions and the management of the services of adjustment of the system.

4.8 Consumption-consumption: These are the deviations caused by the differences between actual production and expected generation, variations in the demand for the system and/or forced modifications of the production programs. as to the existence of significant differences between the expected demand in the Spanish peninsular electricity system and the demand programmed after the results of the different sessions of the intra-day market.

For the resolution of these generation-consumption deviations, the mechanisms described in the operating procedures for the management of the frequency-power regulation services will be applied, and also, when this is applicable, the generation-consumption diversion management mechanism, which is also established in the operating procedures.

4.9 Closing programme (P48RENER): This is the programme which is established at the end of the daily programming horizon and which contains the programmes resulting from the daily operational programme and the different sessions of the In this context, the Commission will be in a position to take into account the changes in the programmes associated with the process of technical restrictions and the participation of the various units in the system and in the system. Generation-consumption deviation management process.

4.10 Nomination of programmes for the implementation of bilateral contracts with physical delivery: The nomination of programmes corresponding to the implementation of bilateral contracts with physical delivery consists of the communication by the Programming Unit of such bilateral contracts to the System Operator in the form and time limits referred to in this operating procedure.

The nominations of the energy programs corresponding to the execution of bilateral contracts with physical delivery will be made by the seller and the buyer, directly or indirectly, to the Operator of the System:

Direct Nomination: Each of the SM that is part of the bilateral contract with physical delivery nominates to the OS the program of energy of the programming units of which it is the holder (or to which it represents), and with which it wishes execute such bilateral.

Indirect Nomination: One of the SM that is part of the bilateral contract with physical delivery is responsible, prior to the corresponding authorization of the SM acting as a counterpart, to make the nomination of the energy program of each and every programming unit with which both SM plans to implement such a bilateral contract. The SM responsible for making the nomination will be called the Nominator Subject. The authorization of the Nominator, to be effective, must be communicated to the OS. The OS will inform the Nominee Subject of the date from which your authorization to nominate is effective. Once a Nominator has been authorised for a bilateral contract with physical delivery, the latter may only be the subject of indirect nomination. In the case of international bilateral contracts outside the scope of the Iberian Market, the indirect nomination may be made only by the incumbent SM (or the representative) of the UP located on the Spanish side of the corresponding interconnection.

5. Pre-day programming of operation

5.1 Integration of energy from primary energy emission auctions (SEP), when the exercise of the options is by physical delivery.

5.1.1 Establishment of bilateral contracts for the nomination of the exercise of the options awarded in the auction of primary energy emissions: Monthly, not less than three working days in advance for the first day of each month, the entity with aggregator function in the primary energy emission auctions (EASEP) shall communicate through the indirect nomination system to the OS:

The relationship of the SM holders of primary emission purchase options, arising from the award in such auctions and the possible bilateral transfers of such options, using for this identification the corresponding Energy Identification Code (EIC) codes.

The maximum power value associated with each buyer SM partner-SM seller, and the validity period of this information.

In this case, for the purposes of the indirect nomination of energy programs, the Entity Aggregator of the Primary Emission Auctions (EASEP) is considered to be part of the bilateral contracts with physical delivery (CBEP) in accordance with the arrangements established between this entity and the SM authorised to participate in the Primary Emission Auctions.

Once the above mentioned information of the entity with aggregator function in the primary energy emission auctions (EASEP) has been received, the OS will automatically generate the corresponding information system bilateral contracts with physical delivery associated with the holding of energy purchase options (CBEP), between each of the SM vendors and those SM holders of such energy purchase options, for the execution of the nomination process programs after the exercise of these primary energy purchase options.

The generated CBEPs will have a maximum power value equal to the maximum value communicated by the EASEP to the OS for each buyer-seller pair and will be valid during the period communicated by the EASEP and may be extended, or, to be modified in its maximum power by the successive communications of the EASEP, remaining unchanged the number of performance of the contract.

These CBEPs will use Generic Programming Units (UPG), both for the seller SM and for the buyer SM, units that will have been previously released, for such purposes, in the information system of the System. The discharge of these UPG shall be requested by the OS by the SM in accordance with the provisions established in this respect in the operating procedures, and shall be communicated to the OM through the means and deadlines established.

The OS will validate that the information received from EASEP refers to SM that has the corresponding UPG for the period of validity indicated in the communication. Otherwise, the communication sent by the EASEP will be rejected.

The OS, once released these CBEPs in your information system, will make available to each SM the information corresponding to these bilateral contracts, with respect to the established confidentiality criteria.

In case the EASEP communicates to the OS the early cancellation of a CBEP contract with an SM, the EASEP will no longer send to the OS, as of the date the cancellation is effective, the nomination of the affected CBEP.

In case the OS, as indicated in the operating procedures, suspends the participation in the market of an SM, it will apply what is established in the corresponding operating procedure with respect to the suspension of the SM on the market, in addition, this suspension, to the Market Operator and, where appropriate, to the entities empowered for the nomination of bilateral contracts. During the period of suspension, the daily nomination of bilateral contracts which were in force in force shall be prevented. When the suspension of the SM is complete, this will be again communicated by the OS to the aforementioned entities.

5.1.2 Nomination of bilateral CBEP contracts associated with the exercise of the energy purchase options of the primary emission auctions: The nomination to the OS of bilateral CBEP contracts associated with the exercise of the energy purchase options after the primary energy auctions shall be made by the EASEP, under the principle of indirect nomination, before 8:45 h of day D-1, in accordance with the arrangements established between EASEP, the SM sellers and the SM buyers forholders of energy purchase options arising from their direct award in the auctions of primary energy emissions, or the subsequent bilateral transfer of such options.

The OS will verify that CBEPs associated with the exercise of primary energy purchase options are nominated for each programming period for a value not exceeding the maximum power of the corresponding CBEP in that period. Otherwise, the nomination of this bilateral contract will be considered invalid and will be rejected. Following this verification, the OS will make available to the SM sellers and buyers the result of the valid nominations of the CBEP, made by the EASEP and corresponding to the exercise of the options for the purchase of energy by the subject holders of those options.

5.2 explicit daily sub-staff of the exchange capacity in the France-Spain interconnection and Interchanges of information prior to the MD concerning the programming of exchanges in such interconnection: Two working days before the day of supply, before 16:00 h, the OS will notify the subjects of the authorizations for the programming, relating to the physical rights of annual and monthly capacity.

The differences between the authorisations for the programming and the physical rights of capacity previously allocated will be the possible capacity reductions due to the identification of a congestion situation in the interconnection.

D-1 day, prior to the closing of the MD, and following the schedules fixed in the operating procedure establishing the resolution of congestions in the France-Spain interconnection and in the Joint Rules of Capacity allocation in the France-Spain interconnection, a series of successive processes will be carried out, in the sequence indicated below:

Before 7:45 h of day D-1, the OS will receive from the subjects the notifications of use of the physical rights of annual and monthly capacity that have been authorized.

The lack of notification of the use of authorised capacity by a market subject within the prescribed time limits shall be construed as an automatic resale in the daily auction of physical capacity rights. corresponding.

The operators of the French and Spanish electrical systems will then exchange information regarding the notifications of use received. On the basis of the results of such exchanges of information concerning the use of the authorised annual and monthly physical capacity, the two OS shall jointly establish the total value of physical capacity assigned and the use of which has been reported on both electrical systems.

The communication by the SM of the execution of one or more bilateral contracts between the Energy Sales Programming Unit for import (or the Unit) will be considered to be a notification of the use of physical capacity. Power purchase programming for export) and Generic Programming Units or Physical Programming Units.

Once the notifications of use of the assigned capabilities are exchanged on an annual and monthly basis, the non-notified usage rights will be automatically resold in the corresponding daily auction. In that same process, the two OS will apply the principle of overlapping firm transactions against management, thereby maximizing the use of the exchange capacity.

Before the time limit set for this information exchange process in Annex I, the OS will make available to the OM the information of the physical rights of assigned capacity in annual and monthly horizons and whose use has been notified in both electrical systems.

Once the above process has been carried out, the operators of both electrical systems will jointly publish the information corresponding to the capacity values that will be offered, in one and another sense of flow, in the Daily explicit auction.

Finally, the operators of both electrical systems will proceed to execute the explicit daily auction, then communicating the results of the same, and the corresponding authorizations for the programming, to all and each of the subjects that have resulted in the capacity to be awarded.

After the daily explicit auction, the OS will make available to the OM the exchange capacity value assigned as a result of the daily explicit auction for each subject in each direction of flow, to the object that it is information is taken into account for the acceptance of offers to the daily market.

5.3 Program Transfer of the Generic Programming Units in the PDBF: The net balance of all transactions associated with the Generic Programming Units of an SM in the PDBF must be null.

In order to cancel the balance of the program transactions of the generic programming units in the PDBF the SM vendors will be able to establish, with respect of the obligations established in the current regulations, the The following types of transactions:

Bilateral contracts with physical delivery between a Generic Programming Unit and one or more Physical Programming Units of the same holder or other subject subject to which a bilateral agreement has been established.

Purchase or power selling transactions established by participating in the daily production market for Generic Offering Units associated with these Generic Programming Units.

Bilateral contracts with physical delivery between Generic Programming Units.

In order to transfer the energy program of the Generic Programming Units through bilateral contracts, the SM will have to be discharged and in effect the bilateral contracts that are necessary, both between two generic programming units, such as between each Generic Programming Unit and the corresponding Physical Programming Units. These bilateral contracts for the transfer of program from the generic programming units to the physical programming units may be national and/or international and must be nominated by the SM according to the rules and deadlines of nomination established in this operating procedure.

5.4 Publication of prior information to the MD: At a time of not less than one hour from the closing of the period of submission of offers to the daily market, the OS will make available to all Market Subjects (SM) and of the Market Operator (OM), as indicated in the operating procedure establishing the exchange of information with the OS, the information concerning the forecast demand, the network situation foreseen for the day next, and for those borders where there is no coordinated capacity management mechanism the provision of exchange capacity on international interconnections (NTC).

At the borders for which there is a coordinated capacity management mechanism, the capacity information made available to the OM and the reporting deadlines for this information will be those indicated in the the procedures for dealing with the resolution of congestion at those borders.

In addition, the system operator will make available to each of the market subjects daily, possible updates of its weekly operating plan, published in accordance with the procedure laid down in the procedure. (a) the operation by which the process for the resolution of supply security restrictions is established, which must be considered as a reason for the development of the forecasts of demand and/or deliveries of production of renewable origin; and/or for over-sold inavailabilities of production facilities and/or elements of the network transport.

5.5 Daily Operating Base Program (PDBF): The OS sets the daily operating base program (PDBF) from:

The valid nominations of the programs corresponding to the execution of bilateral contracts with physical delivery made both before and after the daily market, in accordance with the provisions of this procedure operation.

The information received from the Market Operator concerning energy programmes resulting from the appeal of the tenders submitted to the daily production market.

5.5.1 Nominations of bilateral contracts with physical delivery before the daily market.

5.5.1.1 Primary energy emissions contracts, in the event that they are carried out by physical delivery: Not less than 20:30 hours in advance of D-2, in case the exercise of the options corresponding to the primary emission auctions shall be carried out by physical delivery of energy:

The EASEP will make the first submission to REE of the information needed for the nomination of CBEP programs for day D.

Before 8:45 hours of day D-1, or exceptionally before 8:55 hours, the OS will receive the nomination for:

Bilateral contracts with physical delivery (CBEP) for the exercise of primary energy purchase options. The nomination of programs of these bilateral CBEP type contracts established between the generic programming units (UPG) of the corresponding sellers and buyers, will be realized, under the principle of indirect nomination, by EASEP.

Before 08:50 hours of day D-1, or exceptionally before 9:00 hours, the OS will make available to the SM:

The information corresponding to the nominations of bilateral contracts with physical delivery of type CBEP, with respect to the criteria of confidentiality established in each case.

In the event of any anomaly in relation to the nomination of CBEPs, market subjects will have a deadline of 9:20 p.m. D-1 to be disclosed to EASEP.

In the event of nomination anomalies, EASEP may submit new nominations for bilateral CBEP-type contracts to the OS. The deadline for receipt in the OS of nominations for bilateral CBEP contracts is 9:30 hours of day D-1.

The OS will make available to market subjects the information corresponding to the nominations of bilateral contracts with CBEP-type physical delivery that have been received from the EASEP once the validation has been carried out. corresponding.

5.5.1.2 International contracts: Before 7:45 hours of day D-1:

The OS will receive from the subjects the notifications of use of the physical rights of capacity allocated as a result of the explicit annual and/or monthly auctions in the France-Spain interconnection carried out jointly by the operators of both electrical systems. To this end, the SM shall communicate the execution of bilateral contracts between Physical or Generic Programming Units and the Programming Unit for the purchase or international sale of its authorized entitlement to the SM in the interconnection France-Spain.

Before the time limit set for the exchange of information in Annex I, the OS will receive the nomination corresponding to:

International bilateral contracts outside the scope of the MIBEL with physical delivery in interconnections where there is no coordinated capacity allocation procedure.

International bilateral contracts with physical delivery communicated prior to the daily market in use of the physical rights of capacity allocated in the daily auction in the France-Spain interconnection. The SM may communicate these international bilateral contracts through the use of physical programming units (PUs) or UPG-type Generic Programming Units.

The notifications of use of the physical rights of capacity allocated as a result of the explicit auctions in the Portugal-Spain interconnection carried out jointly by the operators of both electrical systems, once that these auctions have become operational.

These notifications will be made exclusively to the Spanish Electrical System Operator. To this end, the subjects will communicate to the Spanish electrical system operator the execution of bilateral contracts between a Generic Programming Unit located in the Spanish electricity system and a Generic Programming Unit located in the Portuguese electrical system. The Spanish Electrical System Operator will make this information available to the Portuguese Electrical System Operator.

5.5.1.3 National contracts: National bilateral contracts with physical delivery that have chosen the pre-market pre-market nomination option, which may be formalised between two UP, two UPG, or between a combination of both types of Programming Units.

5.5.2 Communication to the OM of information on bilateral contracts nominated before the daily market: Before the deadline set for the exchange of information in Annex I, the Portuguese OS, on behalf of both OS, shall make available to the OM the following information concerning the nomination of bilateral contracts with physical delivery:

Bilateral contracts with physical delivery in the Portugal-Spain interconnection arising from the use of the physical capacity rights acquired in the explicit coordinated auctions between the two OS, once these auctions have taken place running.

Also, before the deadline set for the exchange of information in Annex I, the OS will make available to the OM the information regarding the nomination of bilateral contracts with physical delivery nominated to the OS prior to the daily market.

In the event that you notice that an incident has occurred, the OS, in coordination with the OM, will be able to perform the appropriate actions and, if necessary, new shipments of this information by altering the one already sent. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

5.5.3 Communication to the OS of the outcome of the appeal by the OM: Before 11:00 hours of each day, the OS will receive from the OM the information regarding the result of the appeal of offers in the daily market of production corresponding to the supply units of the Spanish electricity system, with the energy programmes contracted on the daily market, including, where appropriate, the energy programmes resulting from the integration into the market of the contracts established on the market with the physical delivery of the energy, the order of merit of the offers of sale and the energy acquisition resulting from the appeal of tenders at that session of the daily market, and all the tenders submitted to that session.

The OS will also receive from the OM the information regarding the marginal price of the daily market corresponding to the Portuguese and Spanish electrical systems for each programming period.

5.5.4 Reception of nominations after the MD: Before the time limit set for the exchange of information in Annex I, or before 30 minutes after the publication of the information for the Results of the hiring in the daily market, the OS will receive:

Nominations of programs associated with bilateral contracts:

Bilateral contracts with national physical delivery that have not chosen the pre-market firm nomination option. These bilateral contracts may be concluded between two PUs, two UPG, or any combination thereof. This group will include, among others, bilateral contracts with national physical delivery between marketing companies.

Amendments to national bilateral contracts that have chosen the pre-market pre-market nomination option, provided that this modification involves an increase in the firm energy programme previously communicated and not modify the UP and/or UPG with which the bilateral contract has been previously nominated.

Nominations of the programs contracted in the daily market by offer units (UOs) that have two or more programming units (UP):

A managed energy program on the daily production market for each of the programming units (UP) that make up that offering unit (UO).

Program Nominations associated with supply warranty restrictions:

Nominations of the production schedules per unit of programming of the thermal power plants included in the updated operation plan by solution of supply guarantee restrictions having two or more more programming units.

5.5.5 Communication of UP breakdowns and maximum hydraulic powers per UGH: Before the time limit set for the exchange of information in Annex I, or before 30 minutes after the publication of the information corresponding to the results of the procurement in the daily market:

The holders (or their representatives) shall provide the OS with the information corresponding to the program disaggregations of the programming units per physical unit and, if applicable, by units of equivalent production according to the program breakdown criteria that the OS has set specifically for that programming unit.

The holders of hydraulic management units (UGH) shall provide the OS with the information corresponding to the maximum total hydraulic powers per hydraulic management unit (UGH) which, in case they are For system security reasons, they can be supplied and maintained by each UGH for a maximum of 4 and 12 hours.

5.5.6 Elaboration and publication of the PDBF programme: The OS will verify the coherence of the nominations of programmes carried out, directly or indirectly, by the market participants and the information concerning the programmes contracted energy in the daily market, received from the OM.

In the event that as a result of the aggregation of the hiring in the daily market and the bilateral procurement, a marketing programming unit, will result with a vendor program, will proceed from the next:

1. The bilateral contracts between the market participants in which the marketing programming unit is involved shall be ordered in order to increase the volume of daily energy.

2. Bilateral contracts shall be withdrawn in the order indicated until the programme of the marketing unit is null or void at all times.

Also, if as a result of this verification any disparity was detected, among the nominations sent by the subject holders of the programming units or between them and the result of the appeal facilitated by The OM shall proceed, depending on the case, as follows:

Programming units with energy program associated with the execution of bilateral contracts: the minimum value of the programs resulting from the communications made by the different identified subjects will be considered as counterparties in that contract.

Programming units with energy program associated with the procurement in the daily production market that are part of other programming units of the same unit of supply: in those cases where the OS does not received the nomination of programs from the integrated programming units in the same offering unit, or having received such nomination, the total nominated value was different from the program of the corresponding offer unit Statement by the OM, will proceed as follows:

1. The programming units shall be ordered in descending order, taking into account their maximum power value.

2. In accordance with the order of paragraph 1 above, the programming units, the programme values up to a value at the limit equal to the hourly energy corresponding to the maximum power of each programming unit shall be allocated to the programming units, assign the program total of the associated offering unit.

3. If once the programmes have been allocated to all the programming units, in accordance with point 2 above, the programme of the unit of supply has not yet been allocated in its entirety, the difference which will be allocated to the programming unit with the largest maximum power value.

Before the time limit set for the exchange of information in Annex I, or before 1 hour after the publication of the information corresponding to the results of the procurement on the market daily, the OS will make available to all market subjects, and of the OM, the daily operating base program (PDBF) of the programming units of the Spanish electrical system corresponding to the programming of the next day.

From the making available of the daily operating base program (PDBF), the SM will have a maximum period of 30 minutes to make possible claims to the OS due to incidents and anomalies that could be These complaints are dealt with by the procedures laid down for this purpose. In exceptional cases, delays in the publication of the PDBF, or other circumstances as may be necessary, the OS may reduce the length of the period of receipt of possible claims to the PDBF programme, up to a minimum of 15 minutes, previously reporting this reduction of time through the Web of eSIOS Subjects.

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, will carry out the appropriate actions for its resolution and, where appropriate, will proceed with the publication of a new version of the PDBF, keeping the SM of these actions informed at all times, through the website of the eSIOS Subjects. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

5.6 Information receipt after PBF: Before 30 minutes since the publication of the PDBF, the SM must communicate to the OS the energy sales program established in the PDBF necessary for the consumption of gas. (a) Steel of those units of ordinary scheme, not included in Annex II to Royal Decree 134/2010 of 12 February 2010, and which they use as part of the fuel for the generation of steel gas.

5.7 Interim Viable Daily Program (PDVP): Once the PDBF is published, the OS will consider open the bid receipt period for the technical constraint resolution process. This period of receipt of tenders shall be kept open for 30 minutes.

Taking into account the program limitations that may be required for the safety of the electrical system, the OS will first proceed to make the necessary program modifications to include, the thermal generation with the programming units corresponding to the autochthonous coal plants in accordance with the weekly operating plan for supply guarantee restrictions, in their case up to date.

Next, the OS, taking into account the best forecasts of demand and production of wind origin in the Spanish peninsular electrical system and the expected availability of the network facilities and the production, will apply a security analysis on the daily operating base program (PDBF) to detect possible technical constraints and their possible solutions, selecting those that, resolving the restriction with a margin of adequate security, imply lower cost to the system. The OS will do so to make the modifications of the program that are precise for the resolution of the detected restrictions, and will also establish the limitations of program for safety that are necessary to avoid the appearance of new technical restrictions on subsequent processes and markets, in accordance with the procedure laid down in the operating procedure for establishing the process of resolution of technical restrictions.

In this same process, the OS will introduce the required modifications in the PDBF that have been requested by the distribution network managers in those cases where they identify and communicate in a reliable manner to the OS the existence of technical restrictions on the network which is the subject of its management, in accordance with the procedure laid down in the operating procedure for the resolution of technical restrictions.

Following the resolution of the supply guarantee restrictions and the subsequent resolution of the identified technical restrictions, the OS will proceed to apply a reduction of the programmed values to compensate for that energy. incorporated for the resolution of the restrictions by guarantee of supply which has not already been directly compensated by the modifications of the programme for the solution of technical restrictions the net balance of which represents a reduction of the PDBF respecting the limitations of the programme established for safety reasons, by means of the mechanism established in the procedure for the resolution of supply-guarantee restrictions.

Finally, the OS will proceed, if necessary, to make the necessary additional program modifications to obtain a balanced program in generation and demand for the remaining volume, in accordance with the procedure for the resolution of technical restrictions, while respecting the programme limitations established for safety reasons.

The resulting PDVP program will maintain the existing energy flow between the Spanish and Portuguese systems as a result of the daily market's appeal process.

The PDVP program of the programming units located in the Spanish peninsular electrical system resulting from this process will be published by the OS no later than the deadline set for the exchange of information in Annex I, or in any case, prior to the date of 2 hours after the publication of the PDBF, in accordance with the procedure laid down in the procedure for the exchange of information with the OS.

From the making available of the provisional Viable Daily Program (PDVP), the SM will have a maximum period of 30 minutes to make possible claims to the OS due to incidents and anomalies that could be imputable. to the latter, dealing with these complaints in accordance with the procedures laid down for this purpose. In exceptional cases, delays in the publication of the PDVP, or other circumstances as necessary, the OS may reduce the length of the period of receipt of potential claims to the PDVP programme, up to a minimum of 15 minutes, previously reporting this reduction of the deadline via the eSIOS Subject Web.

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, will carry out the appropriate actions for its resolution and, if necessary, will proceed with the publication of a new version of the PDVP, keeping the SM and the OM of these actions informed at all times, through the website of the eSIOS Subjects. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

5.8 Intraday explicit auctions of the exchange capacity in the France-Spain interconnection.

5.8.1 First Intraday Auction of Capacity: Once the PDVP is published, the operators of the French and Spanish electrical systems will exchange, among other things, the information concerning the exchange programs international interconnection between France and Spain, which have been nominated by market participants using the physical rights of capacity allocated in the explicit daily auction jointly implemented by the operators of both electrical systems.

After the exchange of information with the operator of the French electrical system the OS will make available to the OM the capacity effectively nominated in the French and Spanish electric systems to the object that it is information is taken into account in the process of accepting bids in the first-to-fifth sessions, including the intraday market.

On the basis of the results of these programme nominations information exchanges, the two OS will jointly establish the exchange programmes foreseen in the interconnection between France and Spain.

Once these exchange programs are established, the OS will apply the "used or lost" rule to the capabilities assigned on a daily basis and have not been nominated. In the same process, the two OS will apply the overlap of existing firm programs against management, thus maximizing the use of the exchange capacity. Once the above process has been carried out, the operators of both electrical systems will jointly publish the information corresponding to the unused capacity values that will be offered in one and another sense of flow in the First explicit intra-day auction.

Once the explicit intra-day auction is performed, the operators of both electrical systems will proceed to the communication of the results of the same to each and every subject that has been awarded the capacity in the same.

The OS will make available to the SM the total value of the authorizations for programming after such an explicit intra-day auction, indicating the authorized exchange capacity for each subject in each direction of flow.

The OS will make available to the OM the authorizations for the programming established after such an explicit intra-day auction, indicating the total authorized exchange capacity for each subject in each direction of flow, to the the purpose of this information to be taken into account in the process of accepting bids in the first-to-fifth sessions, including the intra-day market.

5.8.2 Second Intraday Auction of Capacity: Once the PHF for the fifth session of the Spanish production market is published, the operators of the French and Spanish electric systems will exchange, the information relating to the international exchange programmes in the interconnection between France and Spain, which have been nominated within the time limits set by the market participants using the physical rights of capacity allocated in the first explicit intra-day auction held jointly by the operators of both electrical systems.

On the basis of the results of these programme nominations information exchanges, the two OS will jointly establish the exchange programmes foreseen in the interconnection between France and Spain.

Once these exchange programs are established, the OS will apply the "used or lost" rule to the capabilities assigned in the intraday horizon and have not been nominated. In that same process, the two OS will apply the overlap of existing firm programs against management, thus maximizing the utilization of the exchange capacity.

Once the above process has been carried out, the operators of both electrical systems will jointly publish the information corresponding to the unused capacity values that will be offered in one and another sense of flow in the second explicit intra-day auction.

Once this second explicit intraday auction is performed, the operators of both electrical systems will proceed to the communication of the results of the same to each and every one of the subjects that have been awarded capacity in the same.

The OS will make available to the SM the total value of the authorizations for the programming as a result of this second explicit intra-day auction, indicating the authorized exchange capacity for each subject in each flow sense.

The OS will make available to the OM the authorizations for the programming established after this second explicit intra-day auction, indicating the total capacity of the authorized exchange to each subject in each direction of flow, to the the purpose of this information to be taken into account in the tender acceptance process for the first four hours of the first session and the sixth session of the intraday market.

5.9 Secondary Regulatory Reserve Requirements: Each day, the OS will set the secondary regulatory reserve requirements for each of the next day's programming periods, as set forth in the the operating procedure for which the reserve for frequency-power regulation is established.

These secondary regulatory reserve requirements required for each programming period of the following day shall be published by the OS before the time limit set for the exchange of information in the Annex. I.

5.10 Secondary Regulatory Reserve Allocation: Once the secondary regulation reserve requirements have been published, the OS will open the period of receipt of bids for the provision of the secondary regulation service, the process to be closed at the time set for these purposes in Annex I, except for another indication of the OS which shall be notified in advance to all MS holders of regulatory areas eligible for the provision of this service.

With the secondary regulation reserve offers received, the OS will allocate the provision of the secondary regulation service with minimum cost criteria, following the process described in the operating procedure whereby the provision of the secondary regulatory service is established.

No later than the time set for the exchange of information in Annex I, the OS shall publish, in accordance with the procedure laid down in the procedure for the exchange of information with the OS, the secondary regulation reserve allocation for each and every programming period of the next day.

From the making available of the secondary reserve allocation, the SM shall have a maximum period of 30 minutes to make possible claims to the OS for incidents and anomalies that may be attributable to the OS, These complaints are dealt with by the procedures laid down for this purpose. In exceptional cases, delays in the publication of the secondary reserve allocation, or other circumstances as necessary, the OS may reduce the length of the period of receipt of possible claims to the allocation. of secondary reserve, up to a minimum of 15 minutes, and previously reporting this reduction of the deadline via the eSIOS Subject Web.

In those cases where the existence of an imputable anomaly to the OS is verified, and the OS can be corrected without affecting the programming process of the generation in an important way, the OS will perform the appropriate actions. for its resolution and will proceed with the publication of a new version of the secondary reserve allocation, keeping the SM of these actions informed at all times, through the website of the eSIOS Subjects.

5.11 Tertiary Regulatory Reserve Requirements: Each day, the OS will establish the tertiary regulatory reserve requirements for each of the next day's programming periods, as set out in the operation procedure whereby the reserve is established for frequency-power regulation.

These tertiary regulatory reserve requirements required for each programming period of the following day shall be published before 21:00 hours of day D-1.

5.12 Tertiary Regulation Offers: Before 23:00 hours of day D-1, the SM will have to present offers of all the tertiary regulation reserve that have available both to increase and to decrease for the entire horizon of the next day's programming, in accordance with the procedure laid down in the operating procedure laying down the conditions for the provision of the tertiary regulatory service. These offers must be continuously updated by the SM whenever modifications are made in the programming or availability of their production units, the offer of the entire reserve of tertiary regulation being obligatory. available on each drive.

6. Intraday (MI) Market

In the schedule set out in Annex I, the OS shall make available to the OM the information relating to the total exchange capacity allocated for each subject in each direction of flow, established after the explicit auction capacity intraday in the France-Spain interconnection applicable to that IM session, in order to ensure that such information is taken into account in the process of acceptance of offers to that IM session.

Programming units affected by bilateral contracts with physical delivery will be able to make program adjustments through the presentation of sales and energy acquisition offerings in the various IM sessions.

According to the schedules set out in Annex I of this procedure, the OS will receive from the OM the information regarding the result of the appeal of offers in the intra-day market of production corresponding to units of the supply of the Spanish electricity system with the energy programmes contracted on the intraday market, the order of merit of the offers of sale and the purchase of energy resulting from the appeal of tenders in that session of the intraday market; and all tenders submitted to that session.

In addition, the OS will receive from the OM the information regarding the marginal price of each of the sessions of the intra-day market corresponding to the Portuguese and Spanish electrical systems for each programming period.

After the communication by the OM of the program resulting from the appeal of offers, for the units of offer located to the Spanish peninsular electrical system, of each of the sessions of the IM, the OS will receive from the subjects holders, the same information provided by them for the preparation of the PDBF:

Program nominations per programming unit (UP), in cases where two or more programming units are integrated into a single offering unit (UO). The nominated programming unit programmes shall respect, where appropriate, the constraints established by security.

In the event that the offering unit has multiple programming units, either the program nomination of the programming units that compose it is not received, or the program nominations are available these programming units, the total nominated value is different from the associated offer unit program communicated by the OM for the corresponding IM session, will proceed as follows, distinguishing between these two possible cases:

A) The offering unit sells energy in the IM:

1. The programming units shall be ordered in descending order, taking into account their maximum power value.

2. In compliance with the order of paragraph 1 above, the programming units, the programme values up to a value at the limit equal to the hourly energy corresponding to the maximum power or the maximum power limit set shall be allocated to the programming units. their case, by system security for each programming unit and thus allocate the total of the associated offering unit program.

3. If once the programmes have been allocated to all the programming units, as referred to in point 2 above, the programme of the unit of supply has not been allocated in full, the difference which will be allocated to the programming unit with a higher maximum power value.

B) The offer unit buyback energy in the IM:

1. The programming units shall be ordered in descending order on the basis of their programmed energy value.

2. In compliance with the order of point 1, the energy of the programming units shall be reduced to a value equal to zero or equal to that of the minimum power limit set, where applicable, by system security or to the allocation of the total of the the program of the associated offer unit married in the corresponding IM session.

Program breakdowns by physical units or, if applicable, by equivalent production units.

The OS, taking into account all the above information, will perform a security analysis to identify any technical restrictions and, if necessary, resolve them by selecting the withdrawal of this process. The Court of First Instance is of the view that the Court of First Instance does not have the right to provide the Commission with a view to the decision of the Court of Justice of the European Union. additional Spanish necessary for the subsequent rebalancing of the resulting programme that session of the IM.

The PHF program of programming units located in the Spanish peninsular electrical system will be established by the OS from the result of the aggregation of all the firm transactions formalized for each period of programming as a result of the daily viable programme and the appeal of tenders on the intra-day market, after having resolved, where appropriate, the technical restrictions identified and the subsequent rebalancing. The PHF programme will maintain the existing energy flow between the Spanish and Portuguese systems as a result of the intra-day market appeal process.

The OS will publish the final schedule (PHF), with a notice of no less than 15 minutes before the start of the horizon for the implementation of the corresponding IM session, in accordance with the procedure of the the operation by which information exchanges with the OS are established.

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, will carry out the appropriate actions for its resolution and, where appropriate, will proceed with the publication of a new version of the PHF, keeping the SM of these actions informed at all times, through the website of the eSIOS Subjects. In the event of such a situation, the OM and the OS shall take the necessary steps to ensure that the sequence of operations is carried out as soon as possible.

In cases where, for some delay or other operating condition, the publication of the corresponding PHF is not possible before the beginning of the horizon of application of an IM session, the OS will suspend the application of the PHF at that time, communicating this fact to the SM, to the OM, to the appropriate effects.

7. Information exchanges after the intraday market for the programming of international exchanges

In order to establish the final values of the exchange programs per subject that will be considered for the establishment of the adjustment value of the frequency-power regulation system in charge of control the exchange of energy between the two electrical systems that share each electrical interconnection, only those energy programs that have been correctly nominated will be considered, and with respect to the deadlines set.

After each session of the IM, the OS will exchange with the operators of the neighboring electrical systems the information of the nominations of energy programs of the SM, in order to establish jointly the the end values of the exchange programs in the corresponding pipeline.

This same exchange of information will also be carried out in cases where a congestion situation has been identified in an international interconnection during the operation in real time, to proceed with the resolution of such congestion through the implementation of a reduction of the planned exchange programmes.

8. Management of deviations

The deviations between generation and consumption over the inavailabilities of the generating equipment and/or modifications in the forecast of the demand and/or in the forecast of the production of special regime not manageable and/or significant differences between the expected demand and the envisaged demand in the market resulting from the market may be resolved by the application of the diversion management mechanism, provided that the conditions for the application of the system are met. the mechanism set out in the operating procedure for which the process of solution of generation-consumption deviations.

The solution of these deviations will cover up to the start time of the application horizon for the next IM session.

9. Real-time programming

9.1 Operational schedules (P48): The P48 are the schedules that result after the incorporation of all the assignments made in firm up to the time of the publication of these programs of the units programming located in the Spanish peninsular electrical system.

Each of the P48 shall be published in accordance with the procedure laid down in the operating procedure establishing the exchange of information with the OS, at a time of not less than 15 minutes in advance of the change of time.

9.2 Immediate actuations to imbalances in real time: At the time when an incident occurs with an imbalance between generation and consumption, the immediate action of the primary and secondary regulation to correct the imbalance, with consequent loss of regulatory reserve.

If the secondary regulation reserve is reduced below desirable levels for system security reasons, the OS will require the use of tertiary regulation reserve to regenerate the secondary reserve, by applying the procedure for the operation whereby the provision of the tertiary regulatory service is established.

9.3 Modifications of the P48: The modification of a P48 from the previous one may be motivated by:

(a) Amendments to the energy sales and procurement programmes carried out in the IM sessions, or by the application of the diversion management procedure, or by the allocation of tertiary regulation offers.

b) Over-come inavailabilities of the physical units of production in the period between the communication of two consecutive P48.

c) Forecasts of the evolution of demand and/or production of wind origin until the next session of the IM, carried out by the OS, and which differ from the total demand and/or the programmed wind production resulting from the previous IM session.

d) A solution for real-time restrictions alert situations.

e) Fehaciente communication of the subject of a production unit, or of a unit of pumping consumption, of the existence of deviations on the program due to the technical impossibility of fulfilling the program, certain discharges, etc.

f) The operator of a neighbouring electricity system operator of the total or partial non-compliance of the energy exchange programme which is intended to be carried out by a market subject.

9.4 Resolution of restrictions detected in real time: The modification of the programming for the resolution of the restrictions identified in real time will be carried out according to the procedure of operation sets the technical constraint resolution process.

10. Close Program (P48DRERE)

After the end of the daily programming horizon, the OS will make available to the subject holders of programming units the closing program (P48REDRE) corresponding to the final production and consumption programs. resulting from the different markets and from the participation in the system adjustment services.

11. Information to the OM and market subjects

All exchanges of information between the OS and the OM and the SM carried out in the framework of the process of programming of the generation, will be carried out using the means and the structure previewed in the current editions of the the procedure laid down for the exchange of information on the OS with the market participants and the joint procedure agreed between the OS and the OM, in accordance with the procedure laid down in the operating procedure for which the information exchanges with the OS.

12. Programming units in the Spanish peninsular electricity system:

The process of daily programming of generation is based on the management of the energy programs of the different programming units corresponding to the sale and the acquisition of energy in the electrical system Spanish peninsular. Some terms associated with the management of the programming units are defined and described in detail below.

12.1 Programming Unit Definition: The Programming Unit is the elementary unit of representation of the energy programs defined in this Operation Procedure.

The Programming Units allow the integration into the Spanish peninsular market of the programs of sale or acquisition of energy corresponding to an individual installation, to which it will be called Physical Unit (UF), or a set of them according to the criteria set out in Annex II to this procedure. They also allow the integration into the market of the import and export programs of energy made through international interconnections.

In Annex II of this procedure, the Generic Programming Unit (UPG) is defined for:

The integration into the energy production market from the primary energy emission auctions (SEP), in case the exercise of options is performed by physical delivery.

The notification of capacity usage in the pipeline with France.

The integration into the production market of engaged generation in physical bilateral contracts.

The Programming Unit (UP) and, where appropriate, the Generic Programming Unit (UPG) is also the elementary unit for the recording of the payment entitlements and the payment obligations that correspond to it in the Register of System Operator Account Log.

The identification codes for these units will be provided by the System Operator once accepted as the Programming Unit and/or the Spanish Electrical System's Generic Programming Unit.

A single Programming Unit and/or Generic Programming Unit may have associated energy programmes corresponding to the different forms of procurement (managed transaction in the organised market and one or more transactions affecting bilateral contracts with physical delivery).

In the case of shared ownership units, the Programming Unit will be unique, and the co-owner who acts at each moment as the controller of the control center of the same will be able to vary in time.

In the case of special regime production units, the Programming Units shall be composed of one or more Physical Units. These Physical Units shall be composed in turn by a set of generation units of special scheme which share the same RAIPRE code (Code of the Administrative Register of Special Regime Production Facilities) and also the economic regime for the sale of energy. Each of these generation units shall be identified by its CIL code (Installation Code for the purposes of the Settlement). The OS shall periodically provide the National Energy Commission with the existing relationship between Physical Units, Generation Units and CIL Codes.

12.2 Programming Unit Holder: The Head of the Programming Unit (and/or Generic Programming Unit) will be the market Subject responsible for the Programming Unit (and/or Generic Programming Unit) in the Spanish production market.

In the case of Programming Units corresponding to production facilities or to direct consumers on the market, the operator of the Programming Unit shall be the owner of the installation, understanding as such subject to the holding of the operating rights of the facility, or the co-owner who exercises at each time as the controller of the control centre of the facility.

In the case of the aggregator Programming Units, which are defined in Annex II, corresponding to the Subject of Representatives, Traders of Last Resource or Traders, the holder of the same shall be the Subject Representative, Last Resource Marketer, or Marketer.

In the case of Programming Units used to integrate into the market the transactions of import or export of energy made through international interconnections, the holder of the Programming Unit shall be the subject of the market which has been authorised for such international exchanges.

In the case of Programming Units used for the integration into the market of energy production from the auctions of primary energy emissions (SEP), the holders of the General Programming Units will be, respectively, the SM seller and the SM holder of power purchase options.

In the case of Generic Programming Units used for the communication of international transactions firm in the interconnection with France the holder of the Programming Unit will be the Subject of the market that has been approved for the implementation of such international exchanges.

It will be up to the Subject Subject:

a) The request for high, low, and communication of modifications relative to the programming unit in the OS information system.

b) Where appropriate, the communication to the OS of the designation of a Representative Subject (RST) for the day-to-day management of that Programming Unit.

c) Communicate to the OS the schedules of energy of that Programming Unit, communicating, in addition, in their case, the Programming Units acting as counterparties in the case of transactions corresponding to contracts bilateral with physical delivery.

(d) to provide to the OS the programmes disaggregated by physical units and/or, where appropriate, equivalent production units, in accordance with the criteria for unbundling of programmes which have been set up by the OS in a specific manner; The Programming Unit.

e) Interlocution for the exchange of information with the OS.

12.3 Representative of the Programming Unit: The Representative of a Programming Unit shall be a subject designated by the titular subject of the Programming Unit to act on behalf of the holder, either in his own name or on behalf of others, on the Spanish Production Market using the same Programming Units as the holder of the holder except in the cases set out in Annex II.

The designation of the Representative of the Programming Unit shall be made by the holder's presentation to the OS of the corresponding power of attorney that accredits this fact.

The Representative of the Programming Unit shall be responsible for the execution of the functions listed in the preceding paragraph in points (a), except for the communication of ups and downs to be performed by the subject (b) the holder of the programming unit, (b) in the case where the representative is no longer representing the holder and (c) to (e), both inclusive.

In those cases where a trader integrates in the market national production of ordinary regime, the trader shall act for all purposes as a representative of the holder of the said Units of Programming.

13. Testing new information systems

Before any new exchange of information is put into operation, the system operator will propose a prior stage of carrying out the relevant information exchange tests between all the subjects. affected.

ANNEX I

Schedules set for information exchanges

1. Schedules for publication of programs and other information exchanges

Concept	Time
Notification to SM authorisations for programming relating to the physical rights of capacity allocated in explicit auctions in the France-Spain interconnection and, where applicable, in the Portugal-Spain interconnection (D-2 or previous day).	D-2. ≤ 16:00 hours.
Nomination of SM to OS (Spanish electrical system) of the capacity allocated in the explicit annual and monthly capacity auctions in the France-Spain pipeline.	≤ 7:45 hours.
The OS makes available to both the OM and the SM the information of the physical rights of capacity obtained in annual and monthly horizons for the France-Spain interconnection, the use of which has been notified in both electrical systems.	≤ 08:15 hours
applicable, EASEP makes an indirect nomination of the CBEPs with formalized physical delivery between UPG of the SM seller and buyer.	≤ 8:45 hours.
appropriate, the OS makes available to the SM the information corresponding to the Bilateral contract nominations with physical delivery of type CBEP.	≤ 08:50 hours
Communication by SM to OS of bilateral contract nominations: International bilateral contracts with physical delivery through of interconnections outside the scope of the MIBEL in which a coordinated capacity allocation procedure is not established. International bilateral contracts with physical delivery in use of physical rights of daily capacity in the France-Spain interconnection which have communicated that contract prior to the day-to-day market. Where applicable, notifications of use of the physical rights of capacity allocated in the explicit auctions in the Portugal-Spain interconnection jointly carried out by the operators of both electrical systems. National bilateral contracts with physical delivery that have chosen the pre-market firm nomination option.	≤ 10:50 hours.
Publication by the OS prior information to the MD.	≤ 11:00 hours.
In your case, the Portuguese OS on behalf of both OS, will make available to the OM: Information regarding the nomination of bilateral contracts with physical delivery in the Portugal-Spain interconnection arising from the use of the physical rights of capacity acquired in the explicit auctions. The maximum capacity values usable in the bidding process on the Daily and Intradiary (ATC) Market.	≤ 11:00 hours.
are available to the OM for information regarding contracts bilateral OS nominated prior to the MD, and the capacity allocated in daily auction on interconnections with coordinated capacity allocation procedure
Publication P&nd.	≤ 13:00 hours.
Sent by SM to the OS of Program Nominations per Programming Unit: Bilateral Contract Nominations after the MD. Program Nominations of UP Programming Units, integrated with other UP in a single offering unit. Nominations of the production programs by the central UP thermal included in the updated operation plan by solution of supply warranty restrictions that have two or more UP. Sending the SM to the OS of the program for: UP breakdowns in UF. UGH maximum hydraulic power.	≤ 13:00 hours. (in any case, up to 30 min. after PDBC is published)
PDBF Publication.	≤ 14:00 hours (in any case, up to 60 min after PDBC publication.
Presentation of offers for technical constraint resolution processing.	Up to 30 min after PDBF publication.
Puesta is available to the SM and the OM of the results of the bilateral contract capacity auction with physical delivery, in case of congestion, on interconnections, outside the scope of the MIBEL, without coordinated capacity allocation procedure.	≤ 16:00 hours.
PDVP publication.	≤ 16:00 hours (in any case, up to 120 min after PDBF publication).
secondary throttling reserve.	≤ 16:00 hours.
power reserve requirements to be uploaded.	After PDVP publication.
Presentation of additional power reserve offerings to be uploaded.	Up to 30 min after publication of the additional power reserve requirements to be uploaded.
Additional power reserve allocation to be uploaded.	≤ 17:00 hours (in any case, up to 60 min after PDVP publication).
Presentation of secondary regulation offerings.	≤ 17:30 hours (in any case, up to 30 minutes after the release of the PDVP, or if applicable, up to 30 minutes after the release of the additional power reserve allocation results to be uploaded.
secondary throttling reserve.	≤ 17:45 hours.
Tertiary Regulation Reserve Requirements.	≤ 21:00 hours.
Presentation of Regulatory Offerings tertiary.	≤ 23:00 hours.

Notes:

D: Programming Day. Except for another indication, all previous schedules correspond to day D-1 (day immediately prior to the operation).

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, through the corresponding specific messages and deadlines for submission, shall carry out appropriate action for its resolution and, where appropriate, shall publish new versions of these publications (Communication from bilateral, PDBF, PDVP and PHF), keeping informed at all times to the SM of these actions, through the Web of the eSIOS Subjects. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

In case of delays in any other publication, schedules are modified as described in the text of the Operation Procedure. If, as a result of these delays, the sequence of programming of the operation is affected, the OS will inform the SM in a timely manner using the Web page of the Market Subjects, the eSIOS.

2. Release schedules for PHFs after intra-day market sessions

Logout

(Time Periods)

	Session 1.	Session 2.	Session 3.	Session 4.	Session 5.	Session 6.
17:00	17:00		21:00	1:00	4:00	8:00	12:00
18:45	21:45	1:45	4:45	8:45	12:45
Cassation	19:30	22:30	2:30	5:30	9:30	13:30
nominations by UP and program disaggregations	20:00	23:00	3:00	6:00	10:00	14:00
Analysis. Recuse after constraints	20:10	23:10	3:10	6:10	10:10	14:10
	PHF Publication	20:20	23:20	3:20	6:20	10:20	14:20
Programming Horizon	27 hours	24 hours	20 hours	17 hours	13 hours	9 hours
(22-24 and 1-24)	(1-24)	(5-24)	(8-24)	(12-24)	(16-24)

3. Schedules of the coordinated system of explicit daily and intra-day capacity auctions in the France-Spain interconnection

Exchange of Nominations between OS

	Daily Auction (D-1)	1. Intra-day Auction (D-1)	2. Intraday Subasta (D)
Preacquired Capacity OS Nomination Limit	7:45	15:00	10:25
7:55-8:05	15:35-15:40	10:35-10:40
Publication of the auction specification	8:35	16:05	11:05
Opening period receipt bids	8:45	16:15	11:15
Receive Period Bids	9:15	16:45	11:45
Communication from the Auction to SM	9:30	17:00	12:00
Communication to the SM and the OM of the assigned capabilities	9:30	17:15	12:15

ANNEX II

Programming units located in the Spanish peninsular electrical system

1. Programming units for energy acquisition

These are the corresponding to the last resort, direct consumers in the market, consumption of pumping, marketers, representatives in their own name, consumption of producers and export of energy to systems external.

a) Programming Unit for the acquisition of energy by marketers of last resort: Each Subject Merchant of last resort with supply at tariff or last resort shall be the holder of a single Unit of Programming for the provisioning of your clients for last resort provisioning.

b) Programming unit for direct energy acquisition by direct consumers on the market: Each Direct Consumer Subject in Market will be the holder of a single Programming Unit for all its supplies within the Spanish peninsular electrical system of which it is a Liquidation Subject.

c) Programming Unit for the acquisition of energy for pumping consumption: Each Producer Subject owner of a pumping facility shall be the holder of a single Programming Unit for the acquisition of energy for pumping consumption of the set of groups coupled in the same knot of the Transport or Distribution Network.

This Programming Unit for pumping consumption of that set of groups, will be different from the Programming Unit that will be assigned to the same installation for the production programming corresponding to the process of turbination of that same set of pumping groups.

(d) Programming Unit for the acquisition of energy for supply to domestic consumers by marketers or representatives on their own behalf and on behalf of others: Each Representative in his own name and on behalf of his/her An employee or a marketer shall be the holder of a single Programming Unit for the supply to all its direct consumer customers within the Spanish peninsular electricity system.

In the event that a direct consumer on a market with a representation on behalf and on behalf of the market operator chooses to be represented, the corresponding representative may use the programming units with which the direct consumer would act on the market.

e) Programming Unit for the acquisition of energy by producers (auxiliary consumption): Each Producer may be the holder of a Programming Unit for the acquisition of energy for the supply of all those ancillary services of its facilities that are not fed from its own production units, with ancillary services being understood as the electrical energy supplies needed to provide the basic service in any of the operation of the plant (load, start, stop and emergency), including supplies to electrical equipment and drives associated with the various processes of the plant, control facilities, telecommunications, mechanical installations and power and lighting.

f) Programming Unit for the acquisition of energy for export from the Iberian electrical system to external systems: Each authorized subject for the export of energy from the Iberian electrical system to systems (a) shall be the holder of a Programming Unit for the integration into the market of the energy export programme through each of the international interconnections for which it has the relevant authorisation, or authorized a transit of energy representing an export operation through such interconnection.

g) Programming unit for the acquisition of energy on the market with the intention of exporting to the French electricity system without having capacity rights: Each Subject authorised for the export of energy to France shall also be the holder of a Programming Unit for the acquisition of energy on the market, without the provision of capacity rights and with the intention of its export to the French electricity system.

h) Programming unit for the acquisition of energy in the market for the supply of energy from the peninsular electrical system to the electric system for the Balearic: Each subject of the electric system to be authorized to the Energy acquisition in the peninsular electrical system will be the holder of a Programming Unit for the integration in the market of the energy program through the link between the peninsular electrical system and the electric system Balearic.

2. Programming units for the sale of energy

These are those for domestic production facilities, belonging to the ordinary regime and special arrangements, imports and sales in the daily market for the excess of the term purchases of the latter resource.

(a) Programming unit for the sale of energy corresponding to the production of ordinary power plants: a Programming Unit shall be set up for each thermal power plant, on the basis of the thermal power plant an electrical power production facility that can operate separately from the other production facilities with which it can share the same connection knot to the Transport Network or the Distribution Network.

A Thermal Programming Unit shall normally be composed of a single physical unit, except in the case of multi-axle power plants, such as certain combined cycle groups (X plus gas turbines and steam turbines), which integrate as many physical units as the number of turbines make up them.

The holder of these Programming Units shall be the same producer as the owner of the plant, or the co-owner who acts at each time as the controller of the control centre of the plant, in the case of central shared ownership.

In case the owner of an ordinary regime production facility decides to establish a marketing contract with a Marketing Subject to integrate its production into the market, this marketer act with the same programming units as the Owner Subject would do.

b) Programming unit for the sale of energy corresponding to the production of hydraulic management units of ordinary regime: A Programming Unit to be called Hydraulic Management Unit (UGH) for each set of hydroelectric power plants belonging to the same hydraulic basin and to the same holder.

The holder of this Programming Unit shall be the Producer Subject itself which owns this set of plants, or the co-owner who acts at each time as the controller of the control centre of the assembly. in the case of shared ownership power stations.

In case the owner of an ordinary regime production facility decides to establish a marketing contract with a Marketing Subject to integrate its production into the market, this marketer act with the same programming units as the Owner Subject would do.

(c) Programming unit for the sale of production of reversible central pumping stations: A Programming Unit shall be set up for each set of groups associated with a reversible pumping station which to evacuate in a certain node of the Transport or Distribution Network and is owned by the same Producer or set of producer subjects.

This Power Selling Programming Unit will be different from the Programming Unit that will be assigned to the same installation for the programming of the pumping consumption of that same set of groups.

The holder of this Programming Unit shall be the Producer Subject itself which owns this set of plants, or the co-owner who acts at each time as the controller of the control centre of the assembly. in the case of shared ownership power stations.

In case the owner of an ordinary regime production facility decides to establish a marketing contract with a Marketing Subject to integrate its production into the market, the marketer act with the same programming units with which the Owner Subject would do so that their performance will be similar to that of a Representative Subject.

(d) The unit for the production of special arrangements for the production of the market in the production market through the producer subject: a production planning unit will be set up. special market regime for each Producer and type subject to the operational classification established by the System Operator and published on the website of the eSIOS market participants. In this way, each producer subject will, at least, have as many special regime programming units as production types, make up their generation park so that each Programming Unit will integrate into the market the production of a single type.

The generation of a special managed character of the same type and producer subject will be assigned to two Programming Units; one that will group that generation enabled for participation in the adjustment services of the potestative system, and another that will group that other generation not enabled for the provision of these potestative services.

In the event that the specific features of any installation make your treatment individualized by the System Operator, the Producer Subject will have the corresponding Programming Unit.

e) Special regime production sales aggregator unit in an integrated market economic regime integrated in the production market through the Subject Marketer or Representative in its own name: Each Subject A marketer or a representative acting in his own name and on behalf of an employed person shall, at least, hold as many special regime programming units under market economic arrangements as rates, in accordance with the operational classification established by the OS, make up the generation park with which you have established contracts of marketing or representation on behalf of an employed person, in such a way that each of its aggregating Programming Units integrates into the market the production corresponding to a single type.

The generation of special managed-character regime of the same type will be assigned to, two Programming Units; one that will group that generation enabled for participation in the adjustment services of the Pothestative character, and another that will group that other generation not enabled for the provision of these services.

In the event that the specific features of any installation make it necessary to be treated individually by the System Operator, the Producer Subject will have the corresponding Programming Unit, which will be integrated into the system by its Representative or Marketer Subject.

Each Marketing Subject or Representative in his own name and on behalf of others may also act with the same programming units with which the Producer Subject would participate in the production market.

f) A special regime production sales aggregator unit under the economic regime of an integrated tariff on the production market through the Producer Subject, Representative on its own behalf or Marketer: Each Subject Owner or Representative acting in his own name and on behalf of an employee or a trader shall be the holder of, at most, three Programming Units for the sale of special regime production on a tariff rate for each of the types, of programming units established and published by the System Operator in the the website of the eSIOS market, which consists of the special regime generation park at the rate it integrates on the market. The first one will integrate the production of power generation units of less than 10 MW of the same type that are exempt from the payment of the cost of deviations, the second will integrate the production of power generation units of inferiora 10 MW of the same type that are not exempt from the payment of the cost of diversion and the third shall integrate the production of power generation units equal to or greater than 10 MW. In this way, each of its aggregating Programming Units will integrate in the market the production corresponding to the production of the same type, power range and of the same way of liquidation of the deviations.

Upon justified request of the Owner or Representative Subject, authorized by the OS, or by direct initiative of the OS, the Programming Units integrating the production of the power generation units equal to or more than 10 MW may integrate the production of power generation units of less than 10 MW not exempt from the payment of the cost of diversion.

As an exceptional case with respect to the provisions of paragraph 12.1 in relation to the composition of the Special Regime Programming Units, the Programming Units that make up the production of generation units power less than 10 MW not exempt from the payment of the cost of deviations and the Programming Units integrating the production of power generation units below 10 MWexempt from the payment of deviations shall be integrated, each, by a Single Unit Physical Unit whose total power will correspond to the sum of the powers of the generation units that make up the said Physical Unit.

Each Marketing Subject or Representative in his own name and on behalf of others may also act with the same programming units with which the Producer Subject would participate in the production market.

g) A special scheme production selling programming unit for installations to which none of the options set out in Article 24.1 of the R.D. 661/2007 is applied to them through Subject Producer or Representative on its own behalf.

According to the current regulations, the market price economic regime is applicable to the facilities during its operation in tests (art. 14.2 of the R.D. 661/2007), to the facilities that have been definitively registered in the Administrative Registry of Production in Special Regime after the date of completion established for their technology (art. 22.2 of R.D. 661/2007) and other facilities on terms that may be established by the regulation.

Two Special Scheme Production Programming Units shall be constituted under the market price economic regime for each Producer and type subject in accordance with the operational classification established by the Operator of the System and published on the website of the eSIOS market subjects. The first of them will integrate the generation of the same type that is in evidence and the second, will integrate the rest of the same type of generation. In this way, each producer subject shall be the holder of so many Special Scheme Programming Units, which do not apply to them any of the options set out in Article 24.1 of the R.D. 661/2007, as types of production. generation park and test situation.

Each individual representative on his own behalf and on behalf of others may also act with the same programming units with which the Producer Subject would participate in the production market.

h) Energy sales programming unit for the import from external systems to the Iberian electricity system: Each authorized subject for the import of energy from external systems to the Iberian electricity system will be the holder of a Programming Unit for the integration into the market of imported energy through each of the international interconnections for which it has the relevant authorisation for the import of energy; or has authorized a power transit that represents an import operation through such interconnection.

i) Programming unit for the sale of energy on the market with the intention of importing from the French electricity system without having capacity rights: Each authorised subject for the import of energy from France shall also be the holder of a Programming Unit for the sale of energy on the market, without the provision of capacity rights and with the intention of importing it from the French electricity system.

It should be noted that facilities which have temporarily suspended the economic regime which they apply to them, or because of the non-compliances referred to in Articles 18, 23.6 and 50 of the R.D. 661/2007 (failure to comply with the obligation to attach to control centres, non-compliance with the documentary record or fraud in the percentages of hybridization and non-compliance with equivalent electric performance), or by application of the request voluntary suspension as set out in Article 49 of the R.D. 661/2007 shall remain under the The Programming Unit corresponding to the sales option that you would have previously chosen.

3. Generic programming units

a) Generic Programming Units (UPG): Generic programming units used for:

The integration into the energy production market from the primary energy emission auctions (SEP), in case the exercise of options is performed by physical delivery.

The notification of capacity usage in the pipeline with France.

The integration into the production market of engaged generation in physical bilateral contracts.

ANNEX III

Programming units located in the Portuguese continental electrical system

The programming units located in the Portuguese electrical system shall be established on the basis of the criteria established by the Portuguese electrical system operator.

ANNEX IV

Statement of high bilateral contracts with physical delivery to the system operator

Bilateral contracts with physical delivery may be established among market subjects (producers, marketers, direct consumers on the market and marketing of last resort) using the physical or generic programming as set out in Annex II.

The bilateral contracts declaration will be made from the SM Web page.

After the high bilateral contract request, the OS will review if the information about the contract is correct and complete and will proceed to communicate the date of discharge to the requesting SM.

International bilateral contracts for the import of energy in the scope of the MIBEL shall be associated only as a selling unit for the corresponding programming unit for the import of energy.

International bilateral energy export contracts in the scope of the MIBEL shall be associated only as a purchasing unit for the corresponding programming unit for the export of energy.

The nomination of these declared contracts to the System Operator shall be in accordance with this procedure and shall respect the schedules of communication to the OS set forth therein.

P. O. -3.2 Resolution of technical constraints

1. Object

The purpose of this procedure is to establish the process for the resolution of the technical restrictions identified in the Spanish peninsular electrical system in the daily program base of operation (PDBF) and in the programs resulting from the different intra-day market sessions, as well as those that can be identified later during the real-time operation.

2. Scope of application

This procedure applies to the following subjects:

a) System Operator (OS).

b) Market Subjects (SM).

In the content of this operating procedure, unless expressly stated to the contrary, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the subject holders of programming units.

3. Resolution of technical restrictions on the daily market

3.1 Reception of the programme resulting from the appeal of the daily market and the nominations of the programme: Within the time limit set in the operating procedure for the programming of the generation, the OS receive from the OM the information concerning the result of the appeal of tenders in the daily production market, with the energy programmes contracted in the daily market, including the energy programmes derived from the integration into the market of the contracts established in the market within the period under the option of the physical liquidation of the energy.

In the time limit set in the operating procedure for the programming of the generation, the OS will receive from the subject holders, for the process of analysis and resolution of technical restrictions, the nominations of the energy schedules for the implementation of bilateral contracts with physical delivery, in accordance with the procedure laid down in the operating procedure for the programming of the generation.

3.2 Disaggregation of the programmes of the sales and energy acquisition programming units and the communication to the OS of other information needed for the security analysis: the operating procedure for which the generation programming is established, the subject holders of programming units shall provide the following information to the OS:

Information for unbundling in physical units of the power program for each programming unit:

The subject holders of each and every programming unit integrated by more than one physical unit shall provide the OS with the information concerning the disaggregations of the energy programmes allocated to each of them. of the physical units that make up each programming unit, so that this information can be taken into account in the system security analysis.

This breakdown of programs will be applicable, in the case of power sales programming units, to all units composed of more than one physical unit and corresponding to:

Sales units corresponding to a thermal power plant (UVT) composed of several physical units (multi-axis thermal units).

Hydraulic Management Units (UGH).

Energy sales units for reversible pumping stations (UVBG).

Energy sales units corresponding to the production of a manageable special regime (UVREG) from non-renewable sources (UVREGNR) and renewable sources (UVREGR).

Energy sales units corresponding to non-manageable special regime production (UVRENG) from non-renewable sources (UVRENGNR) and renewable sources (UVRENGR).

For power acquisition programming units, this program breakdown will include all units composed of more than one physical unit and corresponding to:

Pump Consumption Corresponding Acquisition Units (UAB).

To perform this process of disaggregation of program nominations by physical units, the OS will be able to define and communicate previously to the subject holders of programming units, the criteria, bases and codes use for the realization of these disaggregations. These criteria may be a function of the characteristics of the different programming units and may define the OS for this purpose, equivalent production units comprising a set of physical units of registered net power. less than a certain value, disaggregations by technologies, disaggregations by knots of the network model used by the OS in the security analyses, and combinations of the previous ones.

The holders of hydraulic management units (UGH) shall provide the OS with the information corresponding to the maximum total hydraulic powers per UGH which, in case they are required for safety reasons of the system, can be supplied and maintained by each hydraulic management unit for up to a maximum of 4 and 12 hours.

3.3 Offers for the technical constraint resolution process.

3.3.1 Period for receipt of tenders: Once the PDBF has been communicated, the OS will consider open the period of receipt of offers for the process of resolution of technical restrictions, period that will be closed 30 minutes later of the PDBF communication.

The OS will be able to extend this deadline for receipt of tenders, only in exceptional cases and after communication to all the SM through the SM Web page of the eSIOS system, communication in which the new closing time will be indicated of the period of receipt of tenders, and the specific causes on which the decision to extend the period of acceptance of tenders has been based.

3.3.2 Presentation of offers.

3.3.2.1 Energy Sales Units: The holders of energy sales units, associated with both market transactions and affections to bilateral contracts with physical delivery, corresponding to:

Ordinary regime production.

Non-renewable manageable special regime production.

Energy imports from external electrical systems in which a coordinated system of exchange capacity management is not in place. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

They will present the following offer types:

Power sales offerings that will have a character:

Required for all subjects who hold programming units that, in application of the current regulations, are obliged to make sales offers for each programming period. This obligation shall apply to all the available power in the corresponding programming unit in addition to that programmed in the PDBF, and independently of the fact that its procurement on the production market is carried out through the management of the energy programme in the daily market or through the execution of bilateral contracts with physical delivery.

The production units affected by bilateral contracts with physical delivery, the object of which is the export of energy through electrical interconnections without a coordinated system for the management of the exchange capacity, shall be submit energy sales bids for all the available power in the corresponding production unit, and this independently of the energy sales programme committed in the PDBF, as this PDBF programme, in case of a congestion in the exporting sense in such interconnection, could be reduced or even to be nullified.

Potestative for energy sales units corresponding to energy imports from those external electrical systems in which a coordinated system of exchange capacity management is not in place. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

Power purchase bids that will be mandatory for all sales units with respect to the energy sales program established in the PDBF for the corresponding power sales unit.

The production units of the renewable special management regime (UVREGR) and the non-manageable special regime production units (UVRENG), both non-renewable (UVRENGNR) and renewable, are exempted from this obligation. (UVRENGR), and the units of sale of energy on the market with the intention of importing from the French electricity system without the availability of capacity rights, which will not be able to present specific energy purchase offers.

3.3.2.2 Energy Acquisition Units: The holders of power acquisition units for pumping consumption, associated with both market transactions and affections to bilateral contracts with physical delivery, submit the following offer types:

Energy sales offers that will be mandatory in relation to the corresponding energy acquisition program for the pumping consumption programmed in the PDBF (reduction to the cancellation of the pumping consumption program) of the PDBF).

Power purchase offerings that will have a potestative character, for the increase with respect to the PDBF of the unit's pump consumption program.

3.3.2.3 Generic programming units (UPG and UPGSD): Generic programming units will not participate in the resolution of technical restrictions, not accepting the submission of offers of restrictions for these generic programming units.

3.3.3 Characteristics of the tenders: The tenders for the process of resolution of technical restrictions shall be, in general, simple tenders, and must be submitted by the subject holder of the relevant unit, and (a) irrespective of whether such a unit of sale or acquisition may be partially or wholly affected by one or more bilateral contracts with physical delivery for which its execution has been communicated for the following day.

The following information will be specified for each offer:

Offer type (production, import, or pump consumption).

For each programming period, and with respect to the energy programmed in the PDBF, it will be indicated:

Power to upload:

Block N.: Divisible blocks of rising prices, in order of 1 to 10 (maximum number of blocks).

Energy (MWh).

Power price offered.

Energy to go down:

Block N.: Divisible blocks of decreasing prices, in order of 1 to 10 (maximum number of blocks).

Energy (MWh).

Power price offered.

Code for the definition of the order of precedence to consider for the impact of the possible power redispatches to be applied on a unit of consumption of pumping, and of the possible redispatches of energy to be lowered applied on a unit of sale, if the unit itself participates simultaneously in a market transaction and in the execution of one or more bilateral contracts with physical delivery (priority reduction of the programme corresponding to the market transaction and subsequent reduction of bilateral contracts by pro rata between them, reverse priority, or application of the pro rata rule over the entire transaction set.)

Power sales units for thermal power plants may present complex offers that will consist of four terms:

Revenue to keep the drive coupled for an hour.

Revenue per unit of energy produced.

Cold start revenue.

Revenue by hot start.

In the process of solution of technical restrictions these complex offers may be considered only in cases where the corresponding unit of sale of energy has a schedule null in all and each of the periods constituting the daily programming horizon, or has only one or more energy programmes in one or more of the first three periods of time of that horizon, as a downward ramp of load associated with a drive uncoupling process.

In the case of multi-axle cycles, the hot start of the complex offers may be taken into account in cases where the programme of the unit corresponds to the mode of operation of the a gas turbine and a steam turbine and, by system security requirements, that multi-axle combined cycle group is required in the technical restriction solution processes, the start of an additional gas turbine.

In cases where the complex offer is applicable, upon verification of the above condition, the use of the same shall be performed under the following criteria:

The unit will be considered to remain engaged in a given programming period as long as its production schedule is greater than zero in that period.

The term corresponding to the revenue per unit of energy produced will be specified by a single block.

Hot start: Scheduled start and/or performed by the production thermal unit so that the time interval from the last hour with the allocated program and the time the program is scheduled and/or performed the start is less than 5 hours; and the scheduled start and/or performed by the second and successive gas turbines of a multi-axis combined cycle, in response to a specific request from the OS.

Cold start: Any other scheduled boot and/or performed by the production thermal unit that does not meet the previous condition.

Subject-holders of programming units to which the submission of tenders for the process of resolution of technical restrictions apply may send offers of restrictions by default according to the provided in the operating procedure for establishing the exchange of information with the OS.

3.4 Resolution processing of the technical constraints of the daily operating base program (PDBF): This process consists of two distinct phases:

FASE 1: Modifying the PDBF program by security criteria.

FASE 2: Rebalance of production and demand.

3.4.1 Phase 1: Modifying the PDBF program by security criteria.

The objective of this phase is to determine the technical constraints that may affect the execution of the PDBF, identifying those program modifications that are necessary for the resolution of the restrictions. detected techniques, and establishing the necessary security program limitations to avoid the occurrence of new technical restrictions in the second phase of the technical restriction resolution process and in subsequent markets.

3.4.1.1 Identification of technical constraints.

3.4.1.1.1 Preparation of case studies: Security analysis for the identification of technical restrictions will take into account the following information:

The production and international exchange programs included in the PDBF.

Program breakdowns for:

Power sales units associated with multi-axis thermal power plants (UVT), hydraulic management units (UGH), and reversible pumping stations (UVBG).

Non-manageable (UVREG) and non-manageable (UVRENG) production power sales units, both from renewable sources and non-renewable sources, participating in the market through the corresponding subjects holders or representatives of the same.

The demand predicted by the OS.

The best wind production forecast available on the OS.

The best information available in relation to:

Inavailabilities both programmed and oversold that affect network elements.

Inavailabilities both programmed and oversold that affect the physical units of production and the procurement units for pumping consumption.

The demand will be considered distributed in the different nodes of the network model used by the OS for the performance of the security analyses. This distribution of the demand for knots will be performed by the OS, using the applications of the energy management systems, and the IT applications and Databases specifically designed for the analysis and the resolution of technical restrictions.

3.4.1.1.2 Technical Restriction: It is any circumstance or incident arising from the situation of the production-transport system that, due to the safety, quality and reliability of the established supply (a) Regulation (EC) No No 2014

the European Parliament and of the Council of the European Parliament and of the Council of the European Parliament and of the Council

In particular restrictions may be identified due to:

(a) Failure to comply with security conditions under permanent and/or contingency arrangements, as defined in the operating procedure establishing the operational and security criteria for the operation of the electrical system.

b) Insufficient secondary and/or tertiary regulation reserve.

c) Insufficient additional power reserve to ensure coverage of the expected demand.

d) Insufficient capacity reserve for voltage control in the Transport Network.

e) Insufficient capacity reservation for service replenishment.

For the resolution of these restrictions the mechanisms described in the present operating procedure and those other for which the management of the corresponding adjustment services of the system.

3.4.1.1.3 Safety analysis: On the basis of the above, the OS will carry out the necessary security analyses for the entire programming horizon and identify the technical constraints affecting the PDBF, the safety, quality and reliability criteria contained in the operating procedure establishing the performance and safety criteria for the operation of the electrical system.

These cases of study used for the performance of the PDBF security analyses will be made available to market subjects in RAW format of the PSS/E application after the time period has elapsed. established, where appropriate, for reasons of confidentiality of the information, as indicated in the operating procedure establishing the exchange of information with the OS.

3.4.1.1.4 Resolution of technical restrictions: Before proceeding with the solution of the technical restrictions identified in the Spanish electrical system, the OS will resolve, if necessary, the congestions identified in the PDBF that affect interconnections with neighbouring electrical systems without a coordinated mechanism for the management of the exchange capacity, as laid down in the rules and in the operating procedures in force.

3.4.1.1.5 Resolution of technical restrictions and guarantee of supply in the Spanish electricity system: Once the non-existence of congestion is verified in the international interconnections in which a Coordinated system of management of the exchange capacity, the OS will analyze the security conditions of the Spanish peninsular electrical system and will resolve the restrictions for guarantee of supply that affect the Spanish electricity system agreement with the procedure of operation for which the resolution of restrictions is established by security of supply. In the case of identifying internal technical constraints to the Spanish electrical system in the PDBF, the OS will study for each set of consecutive programming periods in which it has identified technical constraints, possible solutions that they are technically resolved by an appropriate margin of safety.

3.4.1.1.5.1 Means for the resolution of technical restrictions: To resolve the technical restrictions identified in the PDBF affecting the Spanish peninsular electrical system, the OS may establish increases or reductions of the programmed energy in the PDBF.

Increased scheduled power in the PDBF:

Using the power sales offerings presented to the technical constraint resolution process by:

a) Power sales units associated with production facilities:

Units for thermal groups (UVTs).

Hydraulic management units (UGH) and reversible pumping stations (UVBG).

Non-renewable manageable special regime production units (UVREGNR).

(b) Sales units corresponding to energy imports through the electrical interconnections with Community countries (UVICs) without a coordinated system of exchange capacity management.

Reduced power programmed in the PDBF:

The reduction of the programmed energy in the PDBF for the resolution of the technical restrictions identified in the Spanish electricity system, will be carried out without direct use of offers to these effects, being considered these program reductions of the corresponding program provided in the PDBF.

These program reductions for the solution of the technical constraints identified in the PDBF may be applied to the following types of units:

a) Sales units associated with production facilities:

Units for thermal groups (UVTs).

Hydraulic management units (UGH) and reversible pumping stations (UVBG).

Managed Special Regime Production Units (UVREG) and non-manageable (UVRENG), both from non-renewable and renewable sources.

b) Sales units corresponding to energy import programmes through the electricity interconnections with Community countries (UVICs) without coordinated system of capacity management of exchange.

c) Power acquisition units for pumping consumption (UAB).

In the event that other means are not available in the Spanish peninsular electrical system, or there is a certain risk for the supply in the national peninsular territory, the reductions of the programmed energy in the PDBF may also be extended to:

(d) Acquisition units corresponding to energy export programmes through interconnections with neighbouring electrical systems (KAUs) where a coordinated system of management of the system is not in place. ability to exchange.

In exceptional situations, either by lack of means in the Spanish peninsular electricity system or by a certain risk to guarantee the supply in the Spanish peninsular territory, for the resolution of the technical restrictions identified in the PBF, the OS will be able to request the neighboring electrical systems interconnected with the Spanish electrical system, increases and/or reductions of energy programs in units located in their system.

The existence of a coordinated system for the management of exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree is developed, is revised. Decree 2019/1997 of 26 December 1997, for which the electricity production market is organised and regulated.

3.4.1.1.5.2 Selection and application of the means of resolution: Solution of technical restrictions by the increase of the programmed energy in the PDBF: In the case of necessary increases of the programmed energy in the PDBF, and there will be more than one technically valid and equivalent solution, the OS will carry out an economic assessment of the possible solutions and choose the one that represents a lower cost. At the same cost for several equivalent solutions in terms of technical effectiveness for the resolution of the identified restrictions, the OS will select the one that represents a lower energy movement with respect to the PDBF.

Programme increases for the resolution of the technical restrictions identified in the PDBF will be carried out through the implementation of energy redispatches, resulting in new energy programmes that will be established, whenever possible, in whole MWh values, programmes which, in the case of production units, shall be of value not less than the technical minimum of the corresponding unit, nor greater than the maximum power available in the unit, power that at the limit will be equal to the net active power recorded for the same.

Program increments for PDBF that are applied for resolution of technical constraints will be valued on the basis of the offer submitted for the constraint resolution process.

In the case of multi-axle combined cycles, where the programme increases in respect of the PDBF require a change in the mode of operation of a multi-axle combined cycle leading to the start of one or more gas turbines, In addition, the scheduled and realized start of each turbine shall be considered according to the hot start of the complex offer of restrictions that has been submitted.

Solution of technical restrictions by reducing the programmed energy in the PDBF: For the application of reductions of the energy programs provided in the PDBF for the resolution of the technical restrictions identified in the Spanish electrical system will be taken into account the influence that the energy program of each unit has on the technical restrictions identified, using to these effects the factors of contribution to the restrictions techniques obtained in the applied security analyses.

Thus, in the case of multiple units with an equivalent influence on the technical restrictions identified, the resolution of these units will reduce the programs of these units by applying the rule pro rata on their corresponding energy programmes.

In the event that the effects of the programs of these units on the identified restrictions are not equivalent, the modification of programs of the different units will be carried out, in the first place, the program of the unit which has the greatest contribution factor, respecting the minimum production schedule which may be required in this programming unit for the purposes of system security, by applying the following reductions according to the order of decreasing contribution factors obtained in the security analysis applied.

In the event that in the process of resolution of technical restrictions, congestion is identified in the evacuation of production of both ordinary and special regime, being necessary, for reasons of safety of the system, the reduction of the total production program to a certain value, the solution of the technical restrictions identified by the application of the process indicated below:

Identification in the first place of set A of sales units corresponding to production, both ordinary and special arrangements, whose contribution factor to the technical restrictions identified exceeds a certain minimum threshold.

Establishment, from the previous set, of a subset A1 consisting of each and every unit of sale of ordinary regime production (UVT + UGH + UVBG).

Reduction of the programs of the sales units that constitute the A1 subset in order of decreasing contribution factors.

Once applied to the A1 subset, the maximum reduction of programs compatible with the limitations established by reason of the security of the system, in case of persisting the situation of congestion, the OS will proceed to reduce additional production by modifying the programmes of the energy sales units corresponding to the production of special arrangements in accordance with the following order of priority, provided that the security of the system so does allow:

Non-renewable source manageable special regime production units (UVREGNR).

Renewable source manageable special regime production units (UVREGR).

Non-manageable special regime production units from non-renewable sources (UVRENGNR).

Non-manageable special regime production units from renewable sources (UVRENGR), last reducing those units whose technological adequacy, in accordance with the requirements of the operating procedures, contributes to a greater extent to ensure the security and quality of supply conditions for the electrical system.

Program reductions for the solution of the technical constraints identified in the PDBF will be made by applying power redispatches on those units.

This will reduce, first, the programs of the units with the greatest contribution, respecting the minimum production programs that may be required in these units for reasons of system security, and the order of priority referred to above in those cases where the identified technical restrictions have a contribution to both ordinary regime production units and special regime production units.

This process of reduction of programs will, in all cases, give rise to new energy programs that will be established, provided that this is possible, in whole MWh values, programs that, in the case of the units of production, shall have a value not less than the technical minimum of the corresponding unit, and shall not exceed the maximum power available in the unit, the power at the limit shall be equal to the net active power recorded for the unit.

To this end, once the energy sales programmes have been reduced in accordance with the relevant contribution factors to the identified restrictions, or the application, where appropriate, of the pro rata rule for such reduction, a rounding of those programmes shall be established by applying the International Standard ISO 31 B so that all the resulting programmes are expressed in whole MWh values.

The programme reductions for the PDBF that are necessary for the resolution of the identified technical restrictions applied to both energy sales units and procurement units (pumping consumption and, where applicable, (exports) shall be considered as cancellations of the corresponding programme provided for in the PDBF.

Solution of technical constraints due to insufficient power reserve to be raised: In those cases where, once the redispatches have already been incorporated by guarantee of supply, according to the procedure of operation of (i) the resolution of restrictions on security of supply and, the redispatches and security constraints on the PDBF programme necessary for the resolution of technical restrictions, the existence of an insufficient reserve of power is identified; The OS will adopt the following measures in the resulting programme:

Apply minimum program limitations to a value equal to their technical minimum over all the thermal groups scheduled in the PDBF.

Apply maximum program limitations on pump consumption units.

Apply in each electrical interconnection with Community countries a comprehensive minimum programme limitation on all the programming units corresponding to energy imports through the interconnection, for a value equal to the minimum between the overall value of the set of import programmes and the value of the intended exchange capacity and published in the importing sense.

When the above measures are not sufficient to ensure an adequate margin of power reserve to be raised, the OS will schedule the start and coupling of additional thermal groups taking into account for this purpose. the power reserve to be raised that each of the available and uncoupled thermal groups would, where appropriate, contribute to the system, the minimum cold or hot start time, as the case may be, and of the programming declared by the unit (from order to up to a minimum of technical boot), as well as the cost associated with starting and programming coupling of each of them, in order to ensure the additional reserve of power to be raised with the minimum associated cost.

In this process of starting and coupling additional thermal groups, the OS will take into account the possible modes of operation of the multi-axis combined cycles.

The programming cost of a thermal group due to insufficient power reserve to be available will be calculated as the ratio between the programming cost of the group to a technical minimum at all time periods with insufficient power reserve to be raised and, the maximum available power of the group for the number of time periods in which additional thermal group programming is required.

The power reserve provided by each thermal group shall be determined according to the maximum active power available in the unit, the value of which shall be equal to the net active power recorded for that unit of the production.

For this programming of the starting and coupling of additional thermal groups due to the insufficiency of the power reserve to be made available, a specific code of redispatch will be used, preferably, to the object of be able to account individually, both the volume of these redispatches due to an insufficient reserve of power to be uploaded to the system, and the cost associated with the application of the same.

Solution of technical constraints due to insufficient power reserve to be lowered. -In those cases where, once the redispatches and security limitations on the PDBF program necessary for the (i) a reduction in the number of technical restrictions, the identification of the existence of an insufficient reserve of power to be reduced in the resulting programme, the OS may proceed to apply programme limitations on the acquisition units concerned; pumping consumption up to a value equal to that of your program in the PDBF, in order to avoid possible subsequent reductions of this pump consumption program.

3.4.1.1.5.3 Practical implementation of the resolution of restrictions: For the establishment of the energy redispatches necessary for the resolution of the technical restrictions, the values corresponding to the minimum and maximum technical powers of the generating groups, and the nominal powers of the pumping units, according to the information contained in the Administrative Registry of Electrical Power Production Facilities (RAIPEE) and other supplementary information (power corresponding to the technical minimum) of the unit of production, nominal power of consumption of pumping, etc.) which, if it is not contained in the RAIPEE, shall make it easier for the OS to hold the relevant programming units in a feisty form and in accordance with the procedure laid down in the procedure for the operation of the exchanges of information with the OS. In addition, the possible transitional limitations of these power values shall also be taken into account by the subject holders of these units to the OS.

They will not be taken into consideration, on the contrary, other distinct limitations, own of each production unit, such as the maximum ramps of rise and drop of load of the thermal groups, among others, that must be managed on the intraday market, where necessary, by the holders of the relevant units.

The OS at the time of applying energy redispatches to be up on sales units corresponding to reversible pumping stations will take into account the capacity of the upper vessel of the central bank, both in terms of the feasibility of the total energy sales programme which may be required for the resolution of the technical restrictions of the PDBF, as in terms of the feasibility of the necessary pumping programme to be able to take account of that programme for the sale of energy resulting from the resolution of the technical restrictions. This pump consumption program must be established directly by the subject holder of the unit by participating in the intra-day market.

The energy increases programmed over the PDBF for the resolution of technical restrictions in the Spanish electricity system, which can be applied on sales units corresponding to energy imports through interconnections with Community countries without a coordinated system for the management of the exchange capacity shall always take into account the expected and published maximum exchange capacity values for the relevant interconnection and flow direction. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

Once selected, among the set of technically valid, and equally effective, solutions that represent a lower overall cost, the OS will establish, taking into account the increases of the corresponding programs the resolution of restrictions on security of supply, in accordance with the procedure for the operation of the resolution of restrictions on security of supply, the amendments to the programmes corresponding to the resolution adopted, indicating for each unit affected by such modification the type and magnitude of the redispatch which is applicable to you in a specific way, for which the following qualifications will be used:

UPO (Unit with Obtained Program):

Power sales unit for which the coupling or increase of your sales program is required with respect to the PDBF.

Pump consumption unit, or where appropriate, energy acquisition unit corresponding to an export through interconnections with neighbouring electrical systems without coordinated system of capacity management exchange, for which a reduction of its acquisition program with respect to the PDBF is required.

UPL (Limited Program Unit):

Power sales unit for which a reduction in your sales program is required with respect to the PDBF.

Energy redispatches corresponding to the resolution of technical constraints on the daily market, once incorporated into the PDVP, will be considered firm, remaining unchanged in the energy programme even in the the conditions that have resulted in the technical restriction are removed.

In all cases where the resolution of technical restrictions has associated the coupling, increase or decrease of production of specific physical units, incorporated in a given unit of sale of energy, and In addition to the programming unit concerned by the energy redispatch, the physical units and the requirements applicable to each individual unit of the energy sales unit, the OS shall define, in addition to the programming unit concerned, a total change of the programme of the energy sales unit concerned. of them in detail, incorporating these complementary data into areas (a) process of information that will be part of the exchange of information pertaining to the redispatches and security limitations communicated by the OS as part of the PDBF technical restrictions resolution process.

In cases where power redispatches are applied to a programming unit that is integrated by more than one physical unit, security constraints may also affect the same as indicated before. for redispatches, only to part of the physical units that make up the redispatch without considering, in these cases, that these limitations are necessarily applicable to the entire set of the corresponding programming unit.

In the case of the application of redispatches to be lowered on units of sale of energy corresponding to units of production or to imports, or on units of acquisition for consumption of pumping or in its case exports, By participating in the corresponding unit simultaneously in a market transaction and in the execution of one or more bilateral contracts with physical delivery, the OS will distribute the corresponding redispatch on the different transactions in which the unit is involved, taking into account the definition of the order of precedence incorporated in the tender submitted by the holder of that unit for the resolution of the technical restrictions. In the event that the said code has not been included in that offer, the priority reduction of the programme corresponding to the market transaction and the subsequent reduction of all bilateral contracts shall be considered as the default option. in which the same unit is involved by applying prorrata between them, when they are more than one.

In the case of the application of program reductions on units of purchase of pumping consumption or, where applicable, exports, associated with a bilateral physical contract, they will be applied after, in a coordinated manner, applicable, redispatches of energy to be lowered on the sales units associated with that bilateral, in accordance with the provisions of paragraph 3.4.2.1.

3.4.1.1.5.4 Setting of security limitations: As part of the process of resolution of technical restrictions, the OS must establish the necessary limitations, for reasons of system security, on the programmes of the different energy sales units and on the procurement programmes for pumping consumption and, where appropriate, on the programmes corresponding to energy exports through interconnections with the electrical systems neighbors.

The application of these security constraints will aim to avoid the emergence of new restrictions on subsequent processes (rebalance generation-demand, intra-day market, secondary regulation markets, and tertiary, generation-consumption diversion and real-time operation).

The OS will set these program limitations for security according to the following classifications:

LPMI (Minimum Program Limitation or Lower Limit) applicable to:

Power sales unit programmed in the PDBF and/or the PDVP where, for system security reasons, one or more of the physical units that integrate it must maintain a certain minimum energy sales program.

Power acquisition unit programmed or not in the PDBF and corresponding to a pumping consumption or, where appropriate, an export of energy through interconnections with neighbouring electrical systems, in which for reasons Your energy acquisition program cannot exceed a certain value.

LPMA (Maximum Program Limitation or Upper Limit) applicable to:

Power sales unit programmed or not in the PDBF, or programmed in the PDVP where, for system security reasons, your energy sales program cannot exceed a certain value.

Power acquisition unit programmed in the PDBF and corresponding to a pump consumption where for system security reasons its power acquisition program cannot be less than a certain value.

The allocation of security program limitations will impose restrictions on subsequent energy sales and/or energy acquisition programs for pumping consumption and, if applicable, export through the interconnections with the neighbouring electrical systems, for the programming units, or in their case physical units, on which these safety limitations have been applied.

The modification of the energy programs with respect to the PDBF, through the application of energy redispatches of type UPO (unit with program obliged) and UPL (unit with limited program), for the resolution of the restrictions identified techniques, will result in an automatic allocation of security constraints:

(a) The application of power redispatches for the assignment of a required program (UPO) over a particular power selling unit will result in the application of a minimum program limitation (LPMI), limitation that only allow the power redispatches to be applied after the unit (energy sales program increments).

(b) The allocation of a required programme (UPO) on a power acquisition unit for pumping consumption will result in the implementation of a minimum programme limitation (LPMI), a limitation which will only be applied after on this unit redispatches of energy to be raised (reductions of the power acquisition program for pumping consumption).

(c) The allocation of a limited programme (UPL) on a unit of energy sales will result in the implementation of a maximum programme limitation (LPMA), a limitation which will only allow for the implementation of this unit energy to be lowered (reductions in the energy sales program).

The application of security program limitations that set minimum program limits (LPMIs) or maximum program limits (LPMA) on the program of a power sales unit or on the consumer acquisition of pumping or, where appropriate, of export through interconnections with the neighbouring electrical systems without coordinated system of management of the capacity of interchange, will only allow the application of redispatches that respect the limits of power maximum to be lowered or raised, respectively, for them.

These program limitations established for system security reasons may disappear only in those cases where the OS removes or adjusts the corresponding security limitation applied to that unit, the situation of the system-transport system has been modified and the conditions imposing such a programme restriction are no longer present.

When minimum program security (LPMI) or maximum program (LPMA) limitations are associated with particular physical drives and not the unit of sale set, the program limitations for later security markets will also be associated with these physical units and not the energy sales unit as a whole.

In cases where the minimum program limitation (LPMI) or maximum program limitation (LPMA) affects a set of production units or a set of procurement units for pumping consumption, located in the same location, geographical area or international interconnection, the OS shall preferably establish these security constraints in a comprehensive manner, for application to a particular location, geographical area or international interconnection. These global limitations may coexist with minimum program limitations (LPMIs) and/or maximum program (LPMA) limitations applied to one or more of the units to which the global limitation affects.

When on a transient basis, due to an over-coming cause, associated with problems in the operation of the computer applications used for security analysis, or other possible causes affecting the determination and/or treatment of these global limitations, the OS will set these program limits for individual security. For the establishment of such individual limits, on the basis of a level of technical criteria, the OS will use the merit order of the tenders submitted to the technical restrictions resolution process. Irrespective of their contribution to the restriction, they shall be exempted from the application of these programme limitations, provided that the security of the system so permits, all production units of a manageable special scheme renewable (UVREGR) and non-manageable special regime (UVRENG), both from non-renewable and renewable sources.

3.4.1.1.5.5 Treatment of the resolution of technical restrictions in the Distribution Network: In the process of resolution of technical restrictions will be analyzed and resolved the restrictions identified in the transport network, the safety, quality and reliability criteria contained in the operating procedure establishing the performance and safety criteria for the operation of the electrical system.

However, in those cases where the distribution network manager identifies the existence of a safety problem on the network under the production plan, the distribution system operator may request the OS to introduction of the modifications that are required in the PDBF to ensure safety in the affected distribution network.

In such a case, the distribution system operator shall communicate to the OS, in accordance with the operating procedure for the exchange of information with the OS, the risk of exposure to the distribution network which is the subject of its management, the days and periods of programming affected, the measures to be taken, and the changes required in the production programmes, in the event that they are necessary. In this communication, the distribution system operator must explain in detail those requirements, the risk existing in the distribution network and the impossibility of adopting other alternative measures (topological measures or application of the the contracts for the sale of energy by the undersigned with the holders of the production facilities under special arrangements, among others) which could avoid, or at least reduce, the introduction of modifications to the daily base programme intended operation.

In cases where the distribution system operator identifies the existence of restrictions on the network which is the subject of its management as a result of the scheduling of a discharge on the transport network or on the network of distribution, such a manager must communicate this fact to the OS as far as possible, in order to enable such information to be part of the communication of network inavailabilities with influence in the production program that the OS communicates each day prior to the daily market, in accordance with the provisions of the operating procedure for the that information exchanges with the OS are established.

In cases where the above is not possible, for unwanted delays in the communication of such information, or other unanticipated causes, or where the technical restriction is directly associated with the plan itself production provided for in the PDBF, the distribution system operator shall communicate to the OS the existence of such a technical restriction at a time of not less than one hour in respect of the time limit set for the publication of the PDVP of the day in which the programming is carried out and, in any case, prior to the publication by the OS of the energy redispatches and the constraints necessary for security reasons for the resolution of the technical restrictions identified in the PDBF, so that these additional modifications to the PDBF programme can also be taken into account account in the generation-demand rebalancing process.

According to this information, the OS will introduce the required modifications to the PDBF and inform the distribution network manager of the introduction of these redispatches and program modifications. associated, as well as program limitations applied to the security of the distribution network.

For these redispatches and safety limitations applied to the PDBF program for safety reasons of the distribution network, the OS will, preferably, use specific codes in order to be able to establish precisely, their volume, as well as the costs associated with them.

3.4.1.1.5.6 Treatment of congestion identified in the generation evacuation: When in the process of resolution of technical restrictions a situation of congestion due to an excess of production is identified in a a zone with regard to the capacity for evacuation of the same, depending on whether such congestion is already identified in the case-study basis, or that it appears only in the case of certain contingencies, that it will be carried out as indicated below:

a) Condemarches in the case of study and/or identification of conditions of transient post-contingency instability.

Production shall be limited in the area affected by congestion in such a way that at no time on the evacuation lines and transformers are exceeded the maximum load limits set in the operation procedure by the setting the operating and security criteria of the system operation.

This same performance will be carried out in cases where, in the event of contingency, dynamic analyses show the existence of situations of transient instability in a certain area of the electricity system. is weakly attached to the rest of the system or, even at the extreme, practically isolated from it, with a strong production-demand imbalance in the area, which would put the security of supply at risk in the area.

The reduction of the energy programme with respect to the PDBF of the units whose contribution to the identified technical restrictions exceeds a certain minimum threshold shall be made on the basis of their contribution to the restriction the identified technique, taking into account the criteria already mentioned in paragraph 3.4.1.1.5.2.

Thus, in the case of several units whose contribution to the identified technical constraints is equivalent, the energy to be reduced among all of them will be extended according to their planned programme in the PDBF, and in the Other cases for the implementation of these programme reductions shall be taken into account for the factors contributing to the restriction referred to above.

In this process of reducing the energy program with respect to the PDBF, the technical minimum of the thermal groups will be respected. If, once the production of all the groups involved in the congestion has been reduced to the technical minimum, an excess of production will persist in the area, the stop of thermal groups will be programmed, according to the order of merit of the energy purchase offers (reduction of the PDBF programme) submitted for the process of resolution of technical restrictions by the holders of those sales units, initiating the scheduling of the stop of those units which have submitted a higher price on your power purchase offer.

When matching offers at the same price, the thermal group stop will be programmed based on their technical minima, starting with that group with a higher technical minimum, provided the safety of the electrical system so allows it.

In this process of scheduling the stop of thermal groups, the minimum cold start and programming time of the unit (from boot order to technical minimum) must be taken into account, thus being programmed in first place the group stop with a shorter start and/or programming time.

In the particular case where a congestion situation is identified in the production evacuation in which several units belonging to the same SM are involved with a contribution equivalent to congestion, it shall be prorated preferably the energy to be reduced for the congestion solution between the sum of the PDBF program of all the production units belonging to the same SM, and the order of priority communicated to the OS by the corresponding SM will be taken into account for their units when applying the reduction of programs to the production units of each subject, in accordance with the provisions of the operating procedure establishing the exchange of information with the OS and, provided that the security of the system so permits.

The production of special arrangements will also intervene in the resolution of these technical restrictions, in the event that the security of the system so requires, once already reduced to the minimum values compatible with safety of the system, the production schedules of the ordinary system units, following in this process the different phases described in paragraph 3.4.1.1.5.2 of this procedure.

b) Condemarches in post-contingency situations.

Once there has been no evidence of congestion in the case study, or of conditions of temporary instability requiring a priori reduction of production in the area, it has already been resolved that, if necessary, the possible existence of post-contingency congestions will be analysed below.

In the event of such congestion detection, your resolution will be analyzed by adopting corrective measures that will only apply in case of contingencies that cause technical constraints.

Where the adoption of post-contingency corrective measures is not possible, or the implementation of these measures requires a time higher than the time allowed for the consideration of transient overloads in transport elements, In accordance with the procedure laid down in the operating procedure laying down the criteria for operation and safety for the operation of the system, the necessary preventive measures shall be laid down, by means of the reduction of the units of production in the area, applying the same criteria as above for the resolution of congestions in the base case.

c) Teleshots in production units.

In the case of congestion in the production evacuation of a zone limited to post-contingency situations, the production units that may be affected by a reduction, or even by the preventive cancellation of the program In the PDBF, they will be able to avoid, or at least reduce, this decrease in their program, by activating, prior to authorization by the OS, a telefiring automatism of generation that acts in case of any of the contingencies causing unacceptable post-contingency overloads. These automatic generation-firing automatisms may result in the disconnection of the production unit and the complete loss of production of the unit, or a rapid and partial reduction in the production of the unit without disconnection from the production unit. same.

The above will be applicable as long as these tele-firing automatisms act with the required response speed, meet the technical conditions set and are thus enabled by the OS to perform this function, the safety of the electrical system is guaranteed at all times.

In cases where the congestion solution requires the activation of a number of remote-generation tele-firing automatisms to the existing ones, for activation of the same the OS will establish a shift system rotating in the definition of which the holders of the production units of the area provided with telephoto systems may take part.

In the event that the activation of a tele-shot allows to avoid the reduction of the production schedule by such a amount that the reduction requested of the unit that activates said telephoto is exceeded, said additional margin Production will be distributed among the remaining units of production, giving preference to those units which, having a remote-firing system, have not been required, however, the activation of the system is not necessary.

The subject holder of each programming unit shall communicate to the OS, without delay, any change or modification that may affect the operation or operation of these telefiring automatisms.

d) Application of limitations to avoid congestion in later markets for increased production with respect to the PDVP.

In the event that there are no congestions in the baseline case or in post-contingency situation with the energy sales programs in the PDBF corresponding to these production units, but these congestions could if the production units in the area increase their production in subsequent markets (intra-day market, diversion management and tertiary regulation), on top of a certain value, the OS will proceed as follows:

It will determine by horariously, what is the maximum production value that can be allowed in the zone, identifying whether the restriction would be presented only in post-contingency situation, or whether it would correspond to a congestion in the case base.

If possible congestion is identified only in post-contingency situation, it will be determined what is the maximum allowable production value in the area taking into consideration the teleshots of the area groups, these assumptions groups with the same PDVP energy programs.

Once established in both cases the maximum production increase over the programs provided in the PDVP, acceptable for system security reasons, the additional capacity value available (whichever is more In the case of a limited number of groups in the area with influence on congestion, it will be allocated, preferably in the form of a zonal limitation, and alternatively, in the form of an individual limitation on each group of the zone with influence on the congestion, according to order of increasing prices of the offered offers for the process of resolution of technical restrictions by the holders of these energy sales units. In the case of equal price in the offers of two production units, the allowable production increases shall be established by giving preference to the operation of those groups for which their corresponding systems of production have been activated. teleshooting.

3.4.1.1.5.7 Treatment of programme modifications requested by neighbouring electrical systems: The transmission system operators of neighbouring electrical systems interconnected with the Spanish electricity system will be able to ask the OS for the introduction of the modifications that are accurate in the PDBF to ensure security on your network.

In this case, the transmission system operator of the neighbouring electricity system shall be directed in writing-by fax or e-mail-to the OS, informing it of the risk on the transport network which is the subject of its management, and detailing in addition, the days and periods of programming affected, the measures to be taken, and the modifications required in the production programmes, in the event that they are necessary. In this communication, the transmission system operator of the neighbouring electricity system must provide a detailed justification for these requirements, the risk on its network and the impossibility of taking other alternative measures (topological measures or modification of programs in units of their electrical system, among others) that could avoid, or at least reduce, the introduction of requested program modifications.

This information must be communicated by the transmission system operator of the neighbouring electrical system to the OS as far as possible and, in any case, prior to the publication by the OS of the redispatches of energy and the constraints necessary for security reasons for the resolution of the technical restrictions identified in the PDBF, so that these additional modifications to the PDBF programme can also be taken into account in the Generation-demand rebalancing process.

According to this information, the OS will introduce the required modifications to the PDBF and inform the transmission system operator of the electricity system of the introduction of these redispatches and the associated program modifications, as well as program limitations applied to the security of your transportation network.

For these redispatches and safety limitations applied to the PDBF program at the request of the neighboring electrical system, the OS will use, preferably, specific codes to the object of being able to establish with precision, both its volume, such as the costs associated with them which will be borne by the neighbouring electricity system which has made the corresponding application.

3.4.2 Phase 2: Reequilibrium generation-demand: Once the technical restrictions identified in the PDBF have been resolved and, where appropriate, the restrictions for security of supply in accordance with the operating procedure whereby the resolution of restrictions by guarantee of supply is established, the OS will proceed to make the necessary modifications of program in order to obtain a balanced program in generation and demand, respecting the limitations established, system security reasons, in the first phase of the resolution process technical constraints, and the expected and published values of the exchange capacity in international interconnections.

3.4.2.1 Partial or total reduction of the energy sales programmes for bilateral contracts with physical delivery the demand for which has been reduced in PHASE 1.

The OS will first proceed to partially or even totally reduce the energy sales programs of those programming units that are enabled to participate in the restriction resolution process. (a) technical, bilateral contracts with physical delivery whose corresponding demand has been reduced in the first phase of the PDBF technical restrictions resolution process.

According to the provisions of the first phase of the PDBF technical restrictions resolution process, this demand will correspond to pumping consumption units and, when there are no other means to resolve the restrictions or there is a certain risk for the supply in the national peninsular system, to units corresponding to export transactions through the interconnections with the neighbouring electrical systems in which a coordinated system of management of the exchange capacity. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

In the event that the energy sales program associated with that bilateral contract has also been reduced as a result of the solution of restrictions in the first phase of the process, the OS will determine such a reduction. by comparing the following values:

Decrease (D) required in the unit of sale program by the first phase of the technical constraint resolution process.

Partial or total reduction (R) of the unit of sale program associated with the rebalancing of the bilateral contract with physical delivery after the reduction of the acquisition unit program in the first phase of the technical constraints.

This way:

If the decrease (D) is greater than the reduction (R):

The energy sales unit program will be cancelled in accordance with the reduction of the reduced acquisition unit program in PHASE 1 (R) (ECOCBV redispatch).

The difference between the decrease (D) and the reduction (R) will generate a power redispatch to be lowered (D-R) that will be applied on the unit of sale, as a consequence of the resolution of technical constraints by safety criteria (redispatch UPLPVPV).

If the decrease (D) is lower or the limit equal to the reduction (R):

The energy sales unit program will be cancelled in accordance with the reduction of the acquisition unit program applied in PHASE 1 (R) (ECOCBV redispatch).

No power will be generated to be downloaded to the sales unit.

3.4.2.2 Partial or total reduction of energy acquisition programmes corresponding to a pumping consumption or an export through interconnections without a coordinated system of exchange capacity management associated with bilateral contracts with physical delivery the generation of which has been reduced in PHASE 1.

The OS will reduce, or even cancel the energy acquisition programs corresponding to pumping consumption or to exports through interconnections without coordinated system of management of the capacity of exchange which are associated with bilateral contracts with physical delivery, the corresponding generation of which has been reduced in the first phase of the PDBF technical restriction resolution process. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

In the event that the energy acquisition program associated with that bilateral contract has also been reduced as a result of the resolution of restrictions in the first phase of the process, the OS will determine that reduction by comparing the following values:

Decrease (D) required in the acquisition unit program by the first phase of the technical constraint resolution process.

Reduction (R) of the acquisition unit program associated with the rebalancing of the bilateral contract with physical delivery after the reduction of the unit of sale program in the first phase of the technical restrictions process.

This way:

If the decrease (D) is greater than the reduction (R):

The energy acquisition unit program will be cancelled in accordance with the reduction of the reduced unit of sale program in PHASE 1 (R) (ECOCBV redispatch).

The difference between the decrease (D) and the reduction (R) will generate a power re-dispatch (D-R) that will be applied on the acquisition unit, as a result of the resolution of technical constraints by criteria of security (UPOPVPB redispatch).

If the decrease (D) is lower or the limit equal to the reduction (R):

The energy acquisition unit program will be cancelled in accordance with the reduction of the reduced unit of sale program in PHASE 1 (R) (ECOCBV redispatch).

No power will be generated to be downloaded to the sales unit.

3.4.2.3 Obtaining a balanced program generation-demand.

Media for generating-demand rebalancing: To restore balance generation-demand, the OS may proceed to the allocation of the simple bids submitted and accepted for the process of resolution of restrictions techniques for the increase or reduction of the programmed energy in the PDBF by the holders of the following types of units:

a) Power sales units associated with production facilities:

Units for thermal groups (UVTs).

Hydraulic management units (UGH) and reversible pumping stations (UVBG).

Non-renewable manageable special regime production units (UVREGNR).

Non-manageable special regime (UVREGR) and special regime (UVRER) production sales units will not participate in this process.

b) Sales units corresponding to energy imports through interconnections with neighbouring electrical systems without a coordinated system of exchange capacity management (UVI (interconnections with systems) Community electricity and third countries). The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

(c) Units of sale of energy on the market with the intention of their import from the French electricity system without having capacity rights, will not participate in this process.

d) Power acquisition units for pumping consumption (UAB).

The bidding blocks to be allocated will, if any, be the following for those already used in the security criteria constraint resolution process.

Selection and application of the means for generating-demand rebalancing: The OS will determine the modifications to be made to the daily operating base program (PDBF), following the inclusion of the modifications established in the first stage of the process of resolution of technical restrictions which have not been compensated in the process of the resolution of restrictions by security of supply, in accordance with the procedure for the resolution of restrictions for security of supply, in order to obtain a balanced programme in generation and demand in each and every programming period, with the view that these modifications have the least possible economic impact, and in all cases respect the safety programme limitations set out in the first stage of the process and the capacity of exchange in international interconnections.

In case it is necessary to resolve in this phase an excess generation created in the first phase, the OS will determine the units that will be modified its program according to the application of the following criteria:

Allocation of program modifications, first of all, to those units that are required to submit energy offers to be lowered for the process of resolution of technical restrictions, have not been addressed obligation:

In case the modification, compatible with the compliance of the safety criteria, of the programs of this set of units that have not attended to the requirement to present their offers to the OS, exceed the needs In order to reduce energy demand, the programme modifications will be distributed among them by means of a pro rata distribution among all of them.

In the event that after the modification of each and every one of the programs of the units that have not attended to the requirement to present their offers to the OS, still persist a certain imbalance generation-demand, the OS will proceed to the allocation of the energy purchase offers for the reduction of the PDBF programme submitted to the process of resolution of technical restrictions, offers to be allocated according to decreasing offer prices and taking into account the point of operation of the unit.

In the event that a generation deficit resulting from the modification of programmes in the first phase needs to be resolved at this stage, the OS will determine the units that will be modified by the programme according to the implementation of the programmes. following criteria:

Allocation of program modifications, first, to those units that are required to submit energy offers to be uploaded for the resolution of the technical restrictions, have not yet presented these offers:

In case the modification, compatible with the compliance of the safety criteria, of the programs of this set of units that have not attended to the requirement to present their offers to the OS, exceed the needs (i) energy to be increased for the generation-demand rebalancing, the programme modifications will be distributed among them by a pro rata distribution among all of them.

If after the modification of each and every program of the units that have not attended to the requirement to present their offers to the OS, still persist a certain imbalance generation-demand, the OS will proceed to the the allocation of the energy sales offers (increase of the programme of the sales units and/or reduction of the programme of the procurement units corresponding to the pumping consumption) submitted to the process for the resolution of technical restrictions, offers to be allocated based on growing offer prices.

In both cases, if at the end of the assignment there was a price match on more than one offer, not being able to be fully allocated said set of offers of the same price, the allocation will be made by a distribution to prorrata between that set of offers of the same price.

In this apportionment, only the technical minima of those units on which they have been applied, for reasons of system security, minimum program limitations (LPMI), will be respected.

Once a balanced generation-demand programme has been obtained, the OS will proceed to the publication of the provisional Viable Daily Programme (PDVP), in accordance with the schedules set out in the operating procedure under which the programming of the generation.

3.5 Inavailabilities of production units with influence on security, reported after the PDBF has been published: In the case of partial or total unavailability for the programming day of a unit of scheduled or limited production for the resolution of restrictions of the PDBF, if the communication of such unavailability is made at an advance of not less than one hour with respect to the time limit set for the publication of the PDVP in the (i) the implementation of the programme for the implementation of the programme for the implementation of the programme. the restrictions of the PDBF, according to the latest available information regarding inavailabilities of generation.

If the communication of the unavailability is received after the limit time indicated in the preceding paragraph, or, if still known before that time, the reported unavailability affects the Resolution of the restrictions of the PDBF in such a measure that the consideration of the PDBF could delay the publication of the PDVP, and affect subsequent markets, the OS will proceed to publish the PDVP without considering such unavailability generation, addressing the resolution of the technical restriction associated with the existence of this unavailability, once the PDVP has been published.

In order to establish the solution of the technical restrictions, the OS will take into account both the inavailabilities that have been communicated to it by the respective subject holders of programming units through the registers of unavailability, such as other information that has been transmitted to it by the subject holders through other possible means of communication provided with systems of registration.

Once the unavailability of a production unit has been declared, and the unavailability of the PDBF technical restriction resolution process has been taken into account, it has not been applied to this unit. redispatches or program limitations for security, the subject holder of the unit may go to the intraday market and/or participate, if necessary, in a diversion management session to buy back the energy program provided in the PDBF and not can produce, in order to avoid incurring a detour in front of its PDBF program.

In the event that to avoid major delays in the release of the PDVP, the OS has maintained security limitations, and in its case redispatches of power over a production unit for which the holder has communicated an unavailability for the next day, the OS immediately after the release of the PDVP will proceed to enter the detour log for unavailability on the program of said unit, according to the records of unavailability sent by the titular holder, remaining unchanged the limitations by security applied to that unit.

In case of an advance of the availability of the unit on the schedule initially planned, the OS will proceed to the elimination of the log by the declared unavailability, maintaining the unit the program PDVP established for the resolution of the technical restrictions of the PDBF, and the security constraints associated with such programming.

In the event that this advance of the unit availability on the schedule initially planned, occurs however after the production unit has reduced, or even, reached to cancel the affected program by the unavailability by its participation in the intra-day market, or in a call for management of deviations, that production unit may only participate in the programming through the submission of tenders on the market intra-day or, if applicable, a detour management session.

3.6 Information to the OM and market subjects: As a result of the PDBF's technical restrictions resolution process, the OS will make available to the OM and market subjects, as set out in the the procedure for establishing the exchange of information with the OS, the following information:

Information that the OS will make available to the OM:

The security constraints applied to the programs of the sales and energy acquisition units to prevent further technical constraints from being generated in subsequent processes and markets.

The PDVP Interim Viable Program.

Information that the OS will make available to market participants:

The above information made available to the OM.

Energy redispatches applied on the units affected to international bilateral contracts included in the PDBF, resulting from the auction of exchange capacity for the resolution of the identified congestions, where appropriate, in those international interconnections where a coordinated capacity management system is not in place.

The hourly marginal prices resulting from the exchange capacity auctions between international bilateral contracts with physical delivery, applied in those international interconnections in which it is not implemented a coordinated capacity management system.

Energy redispatches applied on market transactions corresponding to imports and/or exports of energy with neighbouring electrical systems, for the solution of congestion in interconnections International interconnections identified in the PDBF in those international interconnections where coordinated capacity allocation systems are not deployed.

The redispatches applied to the programs of the sales and energy acquisition units to resolve the technical constraints identified in the PDBF, associated with both market transactions and contracts bilateral.

The redispatches applied to the sales and energy acquisition units for the generation-demand rebalancing, associated with both market transactions and bilateral contracts.

The OS will also make available to the OM and/or the market subjects any updates to the files previously made available to them in the process of resolution of technical restrictions that has been required.

These exchanges of information will be carried out through the means and with the structure defined in the current versions of the procedure established for the exchange of information of the OS with the subjects of the market and the the joint procedure agreed between the OS and the OM.

3.7 Failure and complaint resolution regarding the PDBF technical restrictions resolution process: The possible identification of anomalies and/or claims submission to the restriction resolution process The PDBF techniques could lead to the repetition of this process in case the solution of the anomaly so makes it necessary, provided that this is possible, with due respect to the maximum permitted time limits established and published by the OS, to ensure that the subsequent processes of the programming of the generation.

Once the PDVP or any of the information media associated with the resolution of the PDBF technical restrictions has been published, the subject holders of the programming units may submit claims to this process, within the time limit set in the operating procedure by which the generation programming is established, by means of the Application of Claims Management made available to these effects by the OS, and may advance the information concerning the existence of this claim, by telephone, fax or electronic mail, where necessary, in any event, the existence of a formal communication expressed through the application of the IT application of claims management, or by a written means (fax or e-mail), for its consideration as formal claim.

4. Resolution of technical restrictions on the intraday market

The OS will communicate each day, in conjunction with the PDVP, and in accordance with the procedures set out in the operating procedure establishing the exchange of information with the OS, the security limitations applicable to both individual programming units such as, where applicable, sets of programming units (zonal constraints), which are to be considered applied on the programmes of the production units, and in their case of importation, and on the programmes of the pumping units and, where appropriate, exports, in order not to change the expected system security conditions.

Throughout the day, the OS will modify these security limitations, and/or incorporate new ones, according to the actual situation of the existing system at any time.

The OS will make available to the OM, before the opening of each session of the IM, the information regarding the security limitations so that these can be taken into account in the process of acceptance of offers of each of the intra-day market (MI) sessions, in the case of security constraints applicable to individual programming units, or within the internal market appeal process itself, in the case of security constraints applicable to the a set of programming units.

Once the outcome of the appeal of each session of the IM is communicated by the OM, the OS shall receive the nominations of programs per unit of programming, in those cases where in the same unit of offer are integrated two or more programming units.

The subject holders of programming units shall provide the OS with the information corresponding to the disaggregations in physical units and/or equivalent production units of the sales and acquisition programmes of the energy, contracted or adjusted in that session.

4.1 Receiving and loading of the result of the appeal from the IM: As a step before the security analysis is carried out, the OS will verify that the program resulting from the appeal of offers in the relevant market session Intraday respects the ability to exchange international interconnections, as well as the security program limitations established by the OS and made available to the OM prior to the opening of the corresponding IM session they are respected, or at least do not keep the solution of their compliance away. If the above does not apply, the OS shall return to the OM, where appropriate, the programme resulting from the appeal of tenders in the IM.

In the event that the obtaining of a program that does not present congestion in the international interconnections was delayed for a time such that it could be affected very important the programming process itself of the generation, there is a high risk of having to suspend the application of the results of that session of the intraday market in some hour, the OS will proceed to solve these congestions, whenever possible, in the own process of solution of technical restrictions of the intra-day market.

4.2 Intraday Market Technical Restrictions Resolution Process: The OS, in the event of identifying any technical constraints that prevent the program resulting from such an intraday market session, also held in the programme nominations per unit of programming communicated by the subject-holders, shall be carried out in compliance with the safety and operational criteria laid down in the relevant operating procedure; selecting the set of offers to be removed that resolve the constraints On the basis of the order of economic precedence of the offers married in the intraday market communicated by the OM, provided that the withdrawal of such offers can be compensated by the withdrawal of other married offers in the same session and also located in the Spanish electricity system, in such a way that it is possible to obtain a balanced program in generation-demand.

The general-demand balance will be re-established by the withdrawal by the OS of other tenders submitted to the intra-day market session, in accordance with the economic precedence of the offers allocated in the that session.

As a result of the process of resolution of technical restrictions on the intraday market, the OS will make available to OM and market subjects the following information:

Information that the OS will make available to the OM:

The Final Schedule Program (PHF) established by the OS as a result of the aggregation of all firm transactions formalized for each programming period as a result of the daily viable program and the Intra-day market after resolution, where applicable, and whenever possible, the technical restrictions identified and the subsequent rebalancing.

Information that the OS will make available to market participants:

The above information made available to the OM.

The power redispatches required to resolve the identified technical constraints.

The power redispatches needed for the subsequent rebalancing of production and demand.

The publication of the Final Schedule Program (PHF) will be performed according to the schedules set in the operation procedure that establishes the generation schedule.

The OS will also make available to the OM and/or the market subjects any updates to the files previously made available to them in the process of resolution of technical restrictions that has been required.

These exchanges of information will be carried out through the means and with the structure defined in the current versions of the procedure established for the exchange of information of the OS with the subjects of the market and the the joint procedure agreed between the OS and the OM.

5. Resolution of technical constraints in real time

5.1 Security Criteria Modifications: The OS will permanently analyze the actual and anticipated security status of the system throughout the entire programming horizon and detect any restrictions that may exist. in each programming period. The resolution of the restrictions will cover the entire programming horizon even if only the energy redispatches will be incorporated in the existing programming periods until the beginning of the programming horizon of the next session of the Intraday market. For the remainder of the period, the necessary limitations for safety reasons shall be established: zonal limitations applicable to a set of individual programming units and/or limitations applicable to a unit of sale or to a unit of energy acquisition, or, to one or more of the physical units that make up the unit.

For the establishment and real-time updating of the safety limits necessary for the resolution of the technical restrictions, the same criteria as referred to in paragraph 3.4.1.1.5.2 of the Annex shall be taken into account. (a) this procedure, thus respecting the values corresponding to the minimum and maximum technical powers of the generating groups and the possible transitional limitations of these power values, without considering any other limitations, such as maximum ramps for loading and lowering the load of the thermal groups, between other, as long as they can be managed on the intraday market by the subject holders of the programming units corresponding to those groups.

Thus, the OS will only program the ramp up/down load of production thermal units when the resolution of technical constraints has been programmed for a programming period such that the subject holder of such a programming unit has no effective possibility to participate in the intraday market session corresponding to the incompatibility of the schedules of that session and the programming period for which the change of the programme of the programming unit for the resolution of the technical restrictions identified in real time.

For the resolution of a real-time technical restriction requiring modification of one or more units ' generation programs, the OS will adopt the resolution representing the minimum cost, using the Tertiary regulation offers that are available at that time.

In the event that the allocation of tertiary regulation offers for the resolution of the restriction is insufficient, this allocation will be supplemented by the allocation of increases and reductions in programmes under the the allocation of the tenders and/or the corresponding offer blocks submitted for the PDBF technical restrictions resolution process, and where applicable, the offer of updated restrictions, with the allocation of the latter modification of programs among the set of units that resolve the constraint, according to the price order of the tenders submitted, the pro rata rule being applied in the case of an equal bid price. In this process of allocation of the offer of restrictions presented, the complex offer may be considered only in cases where the corresponding unit of sale of energy has a zero final schedule in all and each of the periods constituting the programming time horizon, or it has only energy programme in the first three periods of time of the horizon, as a downward ramp of load associated with a process of uncoupling the unit.

In cases where the allocation of programme increments requires a change in the mode of operation of a multi-axle combined cycle leading to the start of one or more gas turbines, the start shall be considered programmed and made of each turbine according to the hot start of the complex offer of restrictions that has been presented.

From the publication of the secondary regulation reserve allocation, market subjects will be able to proceed to update continuously for day D, the offers of restrictions presented for the solution process of technical restrictions of the PDBF, once the necessary computer applications are developed and in accordance with what is established in the procedure of exchange of information with the OS. The OS may delay the opening time for the update of tenders when there are delays in the markets that make it necessary. The SM will be informed through the SM Web of the eSIOS.

In the event that the solution of the real-time restriction requires a reduction in production, inter alia, inter alia, renewable and non-manageable managed special regime production units, these units of production shall maintain its programme without modification, except where the security of the system so requires, once it has been reduced to the minimum values compatible with the safety of the system, the programmes of the other production units intervening in that restriction and taking into account the order of priority set out in the paragraph 3.4.1.1.5.2 of this procedure.

In the event that to ensure system security is accurate the activation of telephoto during the operation in real time, it will apply, if any, the system of rotating shifts established, or in its absence, used as an order criterion to require its activation, that of the tenders submitted for the process of the solution of technical restrictions of the PDBF, except in the case of special regime production, for which activation is required of the telephoto system, only last and following the order of priority set out in the 3.4.1.1.5.2 of this procedure.

The energy redispatches corresponding to the resolution of technical restrictions in real time that have not been effectively executed, will not be considered firm, that is, they will be able to leave without effect the allocations not yet executed when the conditions that gave rise to such a technical restriction are removed.

In cases where the distribution system operator identifies in real time the existence of restrictions on the network which is the subject of its management, in order for the solution to be modified, the production programmes envisaged must be modified. The information referred to in paragraph 3.4.1.1.5.5 of this procedure shall be communicated to the OS, as soon as possible, by all the measures at its disposal by the distribution system operator, as soon as possible.

When the transmission system operator of an electrical system interconnected with the Spanish peninsular electrical system identifies in real time the existence of restrictions in the network object of its management, for which solution It is necessary to amend the production programmes provided for in the Spanish electricity system, once all the measures at its disposal have already been adopted by the neighbouring electricity system, it must inform the OS as soon as possible of the information identified in the Paragraph 3.4.1.1.5.7 of this procedure. The OS shall also proceed as set out in that paragraph of this procedure.

5.2 Treatment of the reductions/cancellations of the capacity to evacuate the production of generator groups due to the over-coming of elements of the Transport Network or the Distribution Network: Due to a breakdown or a fortuitous unavailability is reduced or prevented the ability to evacuate the production of a generator group, being the group available and operating in real time, the OS will proceed to solve the congestion identified in real time by the implementation of a power redispatch on the planned programme for the unit, in such a way that this reduction or cancellation of the capacity for evacuation does not involve a diversion of the actual production of the unit in respect of the planned programme for the unit.

This redispatch will apply from that moment when the capacity for evacuation is affected until the moment when this capacity is already partially or totally restored, proceeding in the first case the OS to adapt the the program of the unit so that it conforms to the actual available evacuation capacity.

In the case of thermal groups, the limitation or, where appropriate, the cancellation of the program of the unit shall be maintained, if necessary, after the capacity of evacuation has been restored, for a period of time equal to the minimum time hot start declared by the unit (from start to sync), or at most, to the start of the application horizon of the next session of the Intradiary Market, in order to allow the unit to recover its program or at least manage the modification of the program in an intraday market session.

5.3 Resolution of restrictions due to insufficient reserve of power to be lowered: When during the operation in real time the existence of an insufficient reserve of power is identified to be reduced in the resulting program, the OS may take the following measures:

Increase the power program of the procurement units for pumping consumption.

Reduce the production schedule of energy sales units for thermal groups up to their minimum allowable power, for safety, or at the limit up to the technical minimum of the unit.

Schedule the stop of thermal groups while respecting the minimum program limitations established by security on the groups and, taking into account the start and programming time of each group. On the basis of technical criteria, the OS will establish a rotating shift system to schedule this stop of thermal groups per reserve of power to fall short.

In the event that the above measures are not sufficient to ensure an adequate margin of power reserve to be lowered in the system, the OS will proceed to reduce the production program of energy sales units. corresponding to the production of a special arrangement, up to its minimum permissible power by security, or in the limit up to the technical minimum of the unit, in accordance with the following order of priority:

Special regime production units manageable from non-renewable sources.

Special regime production units manageable from renewable sources.

Non-manageable special regime production units from non-renewable sources.

Non-manageable special regime production units from renewable sources.

5.4 Resolution of restrictions by action on demand: When during the operation in real time it is not possible to resolve a technical restriction whose solution requires an increase of program of the units production, because these resources have been exhausted or require excessive time, the OS will have to resolve the restriction, or at least alleviate it, by adopting the following measures applied to the demand. This will follow the following order:

Reduction/cancellation of the pumping consumption that might be coupled in the zone.

Reduction/cancellation of export capabilities to other external systems external systems without coordinated mechanism of exchange capacity management and, in case of force majeure, external systems with mechanism coordinated management of the exchange capacity ..

Application of interruptibility to clients with this type of contract, including what is foreseen in the operating procedure by which the operating measures are established to ensure the coverage of the demand in situations Warning and emergency.

Within each category, market criteria shall be applied, whenever possible, conditional on the compatibility of the time required for the application of each of these measures.

Reduction of pumping consumption: For the use of pumping consumption units to solve technical constraints identified in real time, the order of economic precedence of the offers of regulation will be considered It would be up to the holders of such units to upload to the OS, provided that there is no technical condition which prevents the order from being taken into account.

Application for the reduction/cancellation of export capacities: In the event that the above measures are insufficient, and in the area there are energy export programmes through interconnections with the Neighbouring electrical systems, the OS will proceed to the /cancellation of the export capacity.

The operator of the affected neighbouring system will be notified of the reasons for the modification of the swap capacity, the new export capacity value being agreed between the two operators, as well as the hour and minute of the establishment of the new global exchange programme in the adjustment of the frequency-power system regulator regulating the exchange of electricity in such interconnection and, where appropriate, the new exchange programmes authorised in the two senses of flow.

The new exchange capacity will be published in the SIOS, adapting it to the physical reality of the electrical system, and information will be provided on the reasons for the modification.

Reducing export capacity will result in:

Coordinated balance sheet action in those interconnections with coordinated management mechanism, except in case of force majeure, to ensure the intended export programmes.

Reduction of planned exchange programmes, by pro rata, in case of interconnections without coordinated mechanism or in case of force majeure.

Application of the Demand Interruptibility System: The OS will determine the application of the appropriate demand interruptibility to the existing operating circumstances, in terms of type, duration, power and scope of application.

The OS will inform the Management Authority with powers in terms of energy, the NEC and the affected market subjects, on the order of interruptibility given and the reasons for its application.

5.5 Reequilibrium generation-demand after resolution of technical constraints in real time: In the process of solving technical constraints in real time, after the modification of programs by criteria of Security, no systematic process of rebalance generation-demand is established. The possible generation-demand imbalances caused by the real time resolution of the identified restrictions will be resolved, along with the other deviations communicated by the subject holders of programming units, the deviations between the actual and the expected demand for the OS, and the deviations between the actual and the expected wind production, by the use of secondary and/or tertiary regulation energy, or in the event that the required conditions are verified, through of the deviant management mechanism.

6. Settlement of the technical restrictions resolution process

This section describes in general terms the main aspects of the process of resolving technical constraints that have a direct impact on the settlement of this system tuning service.

The calculation of the receivables and the payment obligations arising from the process of settlement of restrictions is defined in the operating procedure whereby payment entitlements and payment obligations are established. by the system tuning services.

6.1 Liquidation of the provision of the technical restriction resolution service: The settlement of the provision of the technical restriction resolution service is established on the basis of the energy released and the prices incorporated in these redispatches, applied in the PDBF technical restrictions resolution process, in the intraday and in real time market, and in cases where applicable, in accordance with the energy measures.

6.1.1 Liquidation of energy programs: The redispatches and prices incorporated in the same applicable to each of the units of sale and acquisition that have modified their program as a consequence of the processes of PDBF Technical Restrictions Resolution, Intradiary Market Technical Restrictions Resolution and Real-time Technical Restrictions Resolution, are specified in the Annex to this procedure.

6.1.2 Liquidation according to energy measures: Settlement with measures shall apply only to:

Power sales units for which, for system security reasons, their coupling and start-up, or an increase in their PDBF programme for the resolution of technical restrictions, have been scheduled identified in this programme (FASE 1), or for the resolution of the technical restrictions identified in real time.

Energy acquisition units on which the costs arising from the technical constraint resolution process are passed on.

6.2 Distribution of cost overruns arising from the process of resolution of technical constraints: Overruns of the PDBF technical restriction resolution process and in real time will be calculated and passed on the criteria specified in the operating procedure for establishing the payment entitlements and the payment obligations for the system adjustment services.

7. Exceptional resolution mechanism

In the event that, in the event of emergencies or for reasons of urgency, either because of the absence of offers due to force majeure or otherwise of an unanticipated or controllable nature, it is not possible to resolve the restrictions by means of the mechanisms provided for in this procedure, the OS may adopt the programming decisions it considers to be more appropriate, justifying its subsequent actions to the affected operators and the NEC, without prejudice the economic settlement of the same as applicable in each case.

ANNEX I

Redispatches and pricing applicable to the provision of the technical constraint resolution service

1. Scheduled redispatches

1.1 Technical restrictions resolution process of the daily operating base program (PDBF).

1.1.1 First phase: PDBF modifications by security criteria.

a) Sales units that increase the programmed energy in the PDBF for the resolution of technical constraints (Unit with Oblinked Program).

Energy redispatches scheduled for the resolution of technical restrictions of the PDBF will incorporate the prices of the simple offer presented by the corresponding unit of sale, except in the case of a a thermal group for which the holder of the unit has submitted a complex offer to the process of resolution of technical restrictions, and is applicable in accordance with the criteria set out in paragraph 3.3.3 of this procedure.

Scheduled units in the PDVP through a simple offer: The UPOPVPV-type power redispatches scheduled in the PDVP on power sales units for resolution of technical constraints will incorporate the price of each of the energy blocks of the simple offer used in whole or in part for the establishment of such redispatch.

Scheduled units in the PDVP through a complex offer: In those cases where the UPOPVPV redispatches are assigned to thermal groups that have submitted a complex offer and this is applicable according to the criteria laid down in paragraph 3.3.3 of this procedure, the energy redispatches shall incorporate the lower price between the following two:

a) The result of applying the complex offer to the program assigned in the PDVP by constraints.

b) The result of applying the complex offer to the final schedule of the unit after its participation in the different sessions of the intraday market and deducting from it the income associated with the valuation to the corresponding one the marginal price of your PDBF programme in descending loading ramp during the first three hours, and the net income (balance between income and payments) resulting from your participation in the various intra-day market sessions.

The calculations made for determining the price that will be incorporated in these redispatches will be applied in both cases on the set of periods that constitute the daily programming horizon, in addition to account, as appropriate, of cold or hot start of the production unit.

Programming with no offer existence for this process, or insufficient existing offering (UPOPVPMER): In cases where the OS has to schedule the entry into operation or an increase of the program of a unit of Energy sales for the resolution of technical restrictions of the PDBF, by means of a redispatch of energy of type UOPPVPMER, not being affected the unit by an unavailability that prevents the realization of the program assigned for safety, and not existing offers submitted for that unit for the constraint resolution process technical, the energy redispatches programmed in each hour will incorporate a price equal to the result of applying a coefficient of majority KMAY, of value equal to 1.15, on the corresponding marginal price of the daily market.

b) Acquisition units and, where applicable, exports to external systems that reduce the programmed energy in the PDBF for the resolution of technical constraints (Unit with Oblinked Program).

UPO-type power redispatches scheduled in the PDVP, respectively, on energy acquisition units or, if applicable, exports, for the resolution of technical constraints, shall be considered equivalent to cancellations of the corresponding programme. Thus, depending on the type of transaction on which they are applied, they will result in the following program modifications:

Daily market transaction (UPOPVPB or UPOPVPE redispatch):

Reduction of the unit acquisition program in the same magnitude as the redispatch applied, incorporating a price equal to the corresponding marginal daily market rate.

Transaction associated with the execution of a bilateral contract with physical delivery (redispatch UPOPVPCBB or UPOPVPCBE):

Reduction of the energy program of the unit of sale and acquisition affects the bilateral contract, in the same magnitude as the redispatch applied, not incorporating this price.

c) Sales units that reduce the programmed energy in the PDBF for the resolution of technical constraints (Limited Program Unit).

UPL-type power redispatches scheduled in the PDVP on power sales units for the resolution of technical constraints, will be considered equivalent to cancellations of the corresponding program. Thus, depending on the type of transaction on which they are applied, they will incorporate the following prices:

Daily Market Transaction (UPLPVPV Redispatch):

Reduction of the energy program of the unit of sale at the same magnitude of the redispatch applied, incorporating this redispatch of program reduction a price equal to the corresponding marginal price of the market journal.

Transaction associated with the execution of a bilateral contract with physical delivery in which the acquisition unit corresponds to a national consumption (UPLPVPCBN redispatch):

Establishment in the PDVP of an energy acquisition program for the unit affects the bilateral contract, through the application on that unit of the corresponding redispatch, incorporating this a price equal to the corresponding marginal daily market time price.

Transaction associated with the execution of a bilateral contract with physical delivery in which the acquisition unit corresponds to a pumping consumption or, where appropriate, an export of energy to external systems (redispatch UPLPVPCB):

Reduction of the energy program of both the unit of sale and the acquisition unit affected to the bilateral contract at the same magnitude of the redispatch applied, not incorporating this price.

1.1.2 Second Phase: General Rebalance-Demand.

a) Sales units with programs associated with bilateral contracts with physical delivery whose demand has been reduced in Phase 1, and which reduce the programmed energy in the PDBF to obtain a balanced program in generation and demand.

ECOCBV energy redispatches scheduled in the PDVP on energy sales units corresponding to bilateral contracts whose demand has been reduced in the first phase of the restriction resolution process PDBF techniques shall not incorporate any price.

(b) Acquisition units corresponding to a pumping consumption or an export through interconnections without a coordinated system of exchange capacity management with programmes associated with bilateral contracts with physical delivery the generation of which has been reduced in Phase I, and which reduces the programmed energy to obtain a balanced programme in generation and demand.

ECOCBV energy redispatches scheduled in the PDVP on energy acquisition units (pumping consumption or, where appropriate, export via international interconnections without a coordinated system of management of the exchange capacity) corresponding to bilateral contracts, the generation of which has been reduced in the first stage of the PDBF's technical restrictions resolution process, shall not include any price.

c) Sales units that increase the programmed energy in the PDBF to obtain a balanced program in generation and demand, and pump consumption acquisition units that reduce the programmed energy in the PDBF with the same end.

Energy redispatches to be uploaded in the PDVP to solve a generation deficit and thus obtain a balanced generation-demand program, applied on a daily market transaction (ECO redispatch) or on a the acquisition unit associated with a bilateral contract with physical delivery (ECOCB redispatch), will incorporate the price of the corresponding block of the offer of energy to be raised by that unit for the process of resolution of restrictions techniques and used in whole or in part for the establishment of such redispatch.

In the case of acquisition units that have not submitted the corresponding offer of energy to be raised for the process of resolution of technical restrictions, being however obliged to do so, the redispatch applied will pass to be referred to as ECOSSO redispatch, if associated with a market transaction, and ECOSCBSO redispatch, if it is associated with a bilateral contract with physical delivery, incorporating in both cases such redispatch a price equal to that resulting from applying a KMIN minoring coefficient, of equal value to 0.85, on the corresponding marginal price daily market time. For these purposes, a default price of the energy supply shall be considered to be raised for the resolution of technical restrictions of the corresponding unit of value equal to 85% of the corresponding marginal daily market time price.

d) Sales units that reduce the programmed energy in the PDBF to obtain a balanced program in generation and demand, and acquisition units that increase the programmed energy in the PDBF for the same purpose.

Power redispatches to be dropped programmed in the PDVP to resolve an excess generation and thus obtain a balanced program generation-demand, applied on a daily market transaction (ECO redispatch) or on a the unit of sale associated with a bilateral contract with physical delivery (ECOCB redispatch) shall incorporate the price of the corresponding block of the energy supply to be lowered submitted by that unit for the process of resolution of technical restrictions and used in whole or in part for the establishment of such redispatch.

In the case of sales units that have not submitted the corresponding offer of energy to be lowered for the process of resolution of technical restrictions, being however obliged to this, the redispatch applied will become referred to as ECOBSO, if it is associated with a market transaction, and the ECOBCBSO redispatch, if it is associated with a bilateral contract with physical delivery, incorporating in both cases a price equal to that resulting from the application of a KMAY, a value equal to 1.15, on the corresponding marginal price of the daily market. For these purposes, a default price of the energy supply to be lowered for the resolution of technical constraints of the corresponding unit of value equal to 115% of the corresponding marginal daily market time price shall be considered.

e) Redispatches applied to obtain a balanced program in generation and demand in the case of insufficient offers to run this process.

In cases where the OS has to schedule power redispatches to go up or down to solve a deficit or excess generation, respectively, and thus obtain a balanced program generation-demand, and once already the redispatches on all the units of both sale and acquisition that are obliged to the submission of offers, have not attended, however, this requirement, and also assigned all those offers presented for the process of resolution of technical restrictions, compatible with the respect of limitations applied for safety, and not yet sufficient allocation to restore the balance generation-demand, the redispatches which, if any, can be applied by the OS by MER, will bear the following prices:

Power Redispatch to Rise (ECOSMER Redispatch): Price equal to that resulting from applying a KMAY mayorance ratio equal to 1.15, on the corresponding marginal daily market time price.

Power Redispatch to Go Down (ECOBMER Redispatch): Price equal to the result of applying a KMIN minoron coefficient, of equal value to 0.85, on the corresponding marginal daily market time price.

1.2 Process of Resolution of Technical Restrictions on the Intradiary Market: The redispatches applied for the withdrawal of offers of sale or purchase of energy from the intradiary market, for the resolution of the the technical restrictions identified in the programme resulting from such an appeal (RTIMO redispatch) or for the subsequent rebalancing of the generation-demand programmes (redispatch ECOMI), shall incorporate the corresponding marginal time-price Intraday market session.

1.3 Process of Resolution of Technical Restrictions in Real Time: Energy redispatches applied for the resolution of technical restrictions identified in real time will incorporate the price of the offers used to these effects: Tertiary regulation offers supplemented by the tenders submitted for the process of resolution of technical restrictions.

1.3.1 Redispatches applied by using the tertiary regulation offering.

1.3.1.1 Sales units that increase your energy program for the resolution of real-time technical constraints and acquisition units that reduce your energy program to the same end.

Power redispatches to upload of type UPOTRT scheduled in real time for the resolution of technical constraints, will incorporate the price of the tertiary regulation offer to be used for these purposes.

1.3.1.2 Sales units that reduce your energy program for the resolution of technical constraints in real time.

Power redispatches of type UPLTRT down scheduled in real time for the resolution of technical constraints, will incorporate the price of the tertiary regulation offer to be used for these purposes.

1.3.1.3 Pump consumption acquisition units that increase your energy program for real-time technical constraint resolution.

The increase of the pump consumption program of a procurement unit for the resolution of technical constraints in real time will be associated with a power redispatch to drop of type UPLTRT. This redispatch shall have an energy equal to the magnitude of the increase in the programme, incorporating a price equal to the sum of the price of the tertiary regulation offer to be used for these purposes, and of the result of applying a KBO coefficient, of a value of 0,70, on the corresponding marginal daily market price.

1.3.2 Redispatches applied by using the submitted offer for the technical constraint resolution process.

1.3.2.1 Sales units that increase your energy program for the resolution of real-time technical constraints and acquisition units that reduce your energy program to the same end.

Power redispatches to upload of type UPOTROR scheduled in real time for resolution of technical constraints, will bear associated the price of the offer of energy to be uploaded for that unit to the process of resolution of technical restrictions and used for these purposes.

1.3.2.2 Sales units that reduce your energy program for real-time technical constraint resolution.

Power redispatches of type UPLTROR to be scheduled in real time for the resolution of technical constraints, will be associated with the price of the offer of energy to be lowered presented for this unit to the process of resolution of technical restrictions and used for these purposes.

1.3.2.3 Pump consumption acquisition units that increase your energy program for real-time technical constraint resolution.

The increase of the pump consumption program of a procurement unit for the resolution of technical constraints in real time will be associated with a power redispatch to be lowered of type UPLTROR. This redispatch will have an energy equal to the magnitude of the increase in program, incorporating a price equal to the sum of the price of the offer of energy to be lowered presented for that unit to the process of resolution of technical constraints and used for these purposes, and for the result of applying a KBO coefficient of 0,70 on the corresponding marginal daily market time price.

1.3.3 Real-time applied redispatches not covered with tertiary regulation offerings or offers submitted for the technical constraint resolution process: In cases where the OS has to schedule redispatches of energy to be raised or lowered for the resolution of technical restrictions identified in real time, without any offers of tertiary regulation, or offers submitted for the process of resolution of technical restrictions, or These are insufficient to cover fully the redispatches applied by the security in real time, the redispatches which, if any, can be applied by the OS by MER, will bear the following prices:

Power Redispatch to Rise (UPPER type): Price equal to the resulting from applying a KMAY shift coefficient, equal to 1.15, over the corresponding daily market time marginal price.

Power Redispatches to Go Down (UPLMER type): Price equal to that resulting from applying a KMIN minoron coefficient, of equal value to 0.85, on the corresponding daily market time marginal price.

In the case of pump consumption acquisition units, the increase of your program for the resolution of technical constraints in real time will bring two energy redispatches to be reduced of type UPLMER. These redispatches will each have an energy equal to the magnitude of the increment of the program, incorporating one of them a price equal to the result of applying a coefficient of minoría KMIN, of value equal to 0.85, on the corresponding price marginal daily market time, and the other a price equal to that resulting from the application of a KBO coefficient, of 0,70, on the corresponding marginal daily market price.

2. Effective execution of scheduled redispatches according to measures

The OS shall determine in accordance with the measures, in those cases where applicable, the modifications that are necessary for the prices incorporated in the scheduled redispatches, taking into account the starts and the type specific starting (cold or hot) scheduled, and the fact that they have been produced effectively in accordance with the measures received, as well as the actual energy measured for the unit and the energy for it programmed by criteria security (Phase 1).

In the event that the energy measured in an hour for a unit of sale is lower than the security programmed, the unfulfilled energy shall be valued at the price resulting from the difference between the weighted average price of the whole energy programmed to rise for the resolution of technical constraints and the corresponding marginal daily market time price.

P. O. -3.8 Participation of production facilities during the pre-operational testing phase of operation in the processes managed by the system operator

1. Object

The purpose of this procedure is to establish the specific requirements and the form of participation of the production facilities in the phase of pre-operational tests of operation in the processes managed by the System Operator.

In particular, this procedure refers to the participation of these production facilities in the following processes managed by the System Operator:

a) Solution of technical constraints in the programs resulting from the daily and intraday markets, and in the operation in real time.

b) Complementary services of frequency-power and voltage control regulation of the transport network.

c) Managing consumption-consumption deviations.

2. Scope of application

This procedure applies to the System Operator (OS), the Market Operator (OM) and the holders (ST) or representatives thereof (RST), of all production facilities that are in the process of testing operation prior to its commercial operation with connection point to the transport network, and of those other than those connected to the distribution network have a registered net power exceeding 50 MW.

In the content of this operating procedure, unless expressly stated to the contrary, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the those subject holders of programming units.

3. Definitions

Operational pre-operational test phase:

It is considered that a production facility is in the phase of pre-operational testing of operation during the period of time since the date on which it is approved, by way of a Ministerial Resolution, Provisional registration for tests in the Administrative Registry of Electrical Power Production Facilities (RAIPEE), with the installation in addition, of the Act of Puesta in Service for tests issued by the Administrative Body competent, and the date of the Ministerial Resolution authorising the final registration of the such installation in the Administrative Registry of Electrical Power Production Facilities (RAIPEE).

Within the term of operational pre-operational tests, all pre-operational tests of the group, including, inter alia, those tests representing an energy delivery to the group, are considered. network, such as those directly associated with the operation of the installation at certain conditions of reactive power generation/absorption.

4. Requirements prior to the execution of the operational pre-operational tests

4.1 Test Authorization: All operational pre-operational tests associated with the connection of the production facility to the transport network, or to the distribution network when its net power registered is more than 50 MW, and regardless of whether or not they give rise to power deliveries to the electrical system, they must be previously authorised by the OS.

For this purpose, the subject-holder of the installation shall provide the OS with detailed information on the planned test plan, within the time limits and form referred to in paragraph 5 of this procedure. In cases where the production facility is connected to the distribution network, the operator holding the installation shall also provide the conformity of the relevant distributor for the performance of these tests.

4.2 Previous General Requirements: As a prior step for the authorization of the operational pre-operational tests, the OS will verify compliance with the following requirements:

1. Availability of the following documentation:

a) Ministerial Resolution approving the provisional registration of the facility for testing in the Administrative Registry of Electrical Power Production Facilities (RAIPEE).

b) A Service for Testing Act issued by the competent Administrative Body.

2. For installations connected to the distribution network:

a) OS Certification of the following requirements:

Compliance with all requirements set out in the Measurement Points Regulation relating to the measurement installation characteristics, measurement equipment verification, high in the Main Concentrator and reception of the measures of the corresponding border point in the system of electrical measures SIMEL, in accordance with the operating procedures in force.

Availability in the OS power control system of the actual installation time of the required installation in the operating procedures.

Verifying the integration of the installation into a control center, enabled by the OS, that acts as an interlocutor with the OS for the real-time operation, as set out in the operating procedures

Availability in the OS database of all the structural information of the required installation at this stage prior to the commercial operation, as provided for in the relevant operating procedures.

b) Certification of the distributor in whose network the installation is evacuated, the compliance with the access procedures and the connection to the Distribution Network.

3. In the case of installations connected to the transport network: Compliance with the procedures for access and connection to the transport network established in the current regulations, the installation of production of the authorization must be available final connection to the transport network in the Verification of Technical Conditions of Connection (IVCTC) report issued by the OS, and the following requirements must be met, among others:

(a) You have signed the technical access contract with the carrier owner of the connection point to the transport network, in accordance with the current regulations.

b) Compliance with all the requirements set out in paragraph 2.a.).

4. In the case of production facilities under special arrangements, copy of the option document for the sale of the energy produced by the installation.

5. Verification of the discharge of the corresponding unit of sale of energy (Requirement applicable to all registered net power plants exceeding 50 MW, and to those production facilities under special arrangements that have chosen the option of free sale of their production).

4.3 Verification of the prior general requirements and communication of their compliance: The OS will verify compliance with the general prerequisites indicated in the previous section and will inform the subject holder of the the production facility, compliance or non-compliance with those requirements, in response to the request for the authorisation of operational pre-operational tests.

In the event that the production facility is connected to the distribution network, the OS will inform the corresponding distributor of the authorization for performance testing at that facility.

5. Communication of the planned test plan and energy deliveries

5.1 Weekly Communication of the Planned Test Plan: Whether or not the facility is directly involved in the market to manage its energy deliveries during the pre-operational testing phase, the subject operator of the production facility shall provide the OS, and also the distributor, when the installation is connected to the Distribution Network, on a weekly basis, before the closing time of the Daily Market on each Friday and for the horizon covering the whole of the following week (Saturday to Friday, inclusive), the following information corresponding to the planned test plan for that week.

Program intended for execution of operational pre-operational tests, in which detail:

a) The expected start date and time of each test.

b) General information about the type of tests that you plan to perform.

c) Test program: expected energy in each programming period.

d) Expected date and time of completion of each test

e) Consequences that would result from a possible requirement for modification of the planned test programme, for the solution of technical constraints, on the test programme itself and its impact on the planned date of start of the group's business operation.

The subject holder of the production facility shall communicate to the OS, as soon as possible, any modifications affecting the weekly test plan previously communicated.

5.2 Update of energy delivery forecasts and program deviation communication: The subject holder of the pre-operational test phase production facility shall provide the OS before the hour. limit set for the publication of the PDBF in accordance with the operating procedure for the programming of the generation of day D-1, whether or not it has managed its energy delivery programmes in the daily market, updated information of the time forecasts for the delivery of energy to the network for the day D, corresponding to the performance tests that the installation plans to perform.

You must also communicate to the OS the days D-1 and D, as far as possible, updated information of the forecast of energy deliveries to the network, in all those cases in which the new forecast of hourly energy represents a variation greater than 30 MWh, in relation to the value of the time energy previously reported for that unit.

In cases where the energy delivery programmes are managed directly in the Spanish production market, the subject of the installation shall inform the OS immediately of any deviation from the production in respect of the programme representing or going to represent a variation of more than 30 MWh in relation to the value of the schedule schedule previously provided for the unit, and the subject holder of the programme shall also be made explicit. unit of sale of energy, the intended duration for this diversion.

These detour communications with respect to the program provided to the OS by the subject holder of the installation, will give rise to redispatches of detour statement applicable on the corresponding units of sale of energy, deviations that will be managed in the same way as the reported deviations for the energy sales units for production facilities in commercial operation.

5.3 Media for communication of this information: Communication between the System Operator, the Market Operator and the subject holders of energy sales units for stage production facilities (a) the operational pre-operational tests shall be carried out through the means and with the structure established in the current versions of the procedure laid down for the exchange of information on the OS with the subject-holders and the the joint procedure agreed between the OS and the OM, in accordance with the procedure laid down in the the operation by which information exchanges with the OS are established.

6. Communication of inavailabilities

All production facilities in the pre-operational test phase of operation, after the satisfactory completion of the continuous operation at full load for 100 hours, must be communicated to the OS all those inavailabilities of active power and/or reactive power affecting or affecting their generating capacity, in order to enable the OS to be able to know at all times the means of production and reserves of power available.

7. Participation of production facilities during the pre-operational testing phase of operation in the system operation processes

7.1 Technical constraint solution process.

7.1.1 Operating base program (PBF) technical constraint solution

a) Offering Presentation:

Operational pre-operational test-stage production facilities may submit specific offers for the resolution of technical restrictions by increasing and/or reducing their programme of production. production.

b) Participation in Phase 1: Modification of the PBF program by security criteria.

In this Phase 1, for the resolution of the technical restrictions identified in the PBF, the OS may apply minimum production limitations, in accordance with the operating procedure under which the resolution of technical restrictions, on the production schedule of those installations at the stage of pre-operational operational tests which have submitted an offer of restrictions on the sale of energy, representing an increase in the programmed energy on the PBF for that drive.

If in this Phase 1 of the PBF technical restriction solution process, it would be necessary to reduce production for the solution of the identified restrictions, these modifications will not affect the production schedule, or the forecast of energy deliveries reported for the groups that are performing pre-operational tests of operation, provided that other means are available to resolve the identified technical constraints.

In case of no other means for the solution of the technical restrictions of the PBF, for reasons of security of the system the OS will proceed to request, in the first place, the reduction of the production of those pre-operational testing facilities which have communicated only forecasts for energy deliveries, and not specific production programmes established by means of participation in the bilateral production and/or procurement market. Where the previous production reduction is not sufficient, the OS shall also apply maximum production constraints on the production schedules of the pre-operational test-stage production facilities which have been presented an offer of restrictions for the reduction of its programme and, finally, on the production programmes of the pre-operational testing facilities which have not submitted such an offer, although in both cases these limitations shall not generate energy redispatches, except in real time, if these are maintained security constraints by persisting unfavorable conditions.

For the application of these maximum production limitations, should more than one group in pre-operational testing with production schedule be affected by a specific supply of restrictions for the production of the reduction of its production schedule, the OS will take into account the order of merit of the offers of energy purchase submitted for the solution of technical restrictions. When multiple offers are matched at the same price or more than one pre-operational test group that has not submitted an offer, the OS will take into account the particular phase of evidence in which each of these groups and the plans of the (a) the evidence communicated to the Commission for the purpose of implementing the restriction solution associated with the least possible disturbance of the test programmes reported for these groups.

c) Participation in Phase 2: Rebalance of production and demand. In this Phase 2, the production facilities at the stage of pre-operational operational tests which have submitted technical restrictions offer, in accordance with the operating procedure for the resolution of the technical constraints.

7.1.2 Solution of technical constraints on the intraday market: Production facilities in pre-operational testing phase will not participate in the process of solution of market technical constraints intra-day, except where there are restrictions and it has been previously verified that such a restriction cannot be resolved by the withdrawal of other tenders submitted to the same session, nor by the subsequent amendment of the programme of other production units in application of the solution mechanism restrictions in real time. In such a situation, partial or total withdrawal as necessary shall be made for the tenders corresponding to the pre-operational test-stage production facility submitted to the relevant intraday market session and which generate constraints.

In the event that in the solution of the restriction more than one group is involved in pre-operational testing, the restriction will be resolved on the basis of the order of economic precedence of the offers married at that session of the ME.

Production facilities in the pre-operational testing phase will not be involved in the process of re-balancing generation-demand after the resolution of the technical constraints of the corresponding one. IM session.

7.1.3 Real-time technical constraint solution: In case of emergency situations or emergency reasons, there are no generation resources available in the system to resolve technical constraints identified, the OS will be able to request production facilities at pre-operational testing stage, increase or reduction of its production schedule, using specific restrictions on the production of the product. submitted by those facilities and, failing that, in application of the exceptional mechanism of resolution set on the operating procedures.

For the implementation of this mechanism, in the event of more than one group being affected in pre-operational testing, the OS will take into account the offers of restrictions that have been submitted for such facilities and the order of merit of the same, and failing or when they match more than one offer at the same price, the specific stage of evidence in which each of these groups is found and the plans for the tests communicated, in order to implement the solution leading to them associated with the least possible disturbance of the test programs reported for these groups.

In the event that several production facilities can participate in pre-operational operational testing and have not submitted a specific offer of restrictions, the OS will proceed to modify as a priority. the production programmes of those installations which have submitted the relevant offer of restrictions.

7.2 Provision of complementary services and participation in the process of management of shift-consumption: Production facilities in the pre-operational testing phase will not be able to participate in the complementary primary, secondary and tertiary regulation services, voltage control of the Transport Network, and management of generation-consumption deviations, until their final registration in the RAIPEE.

Groups in pre-operational testing may not be integrated into a secondary regulatory area before being permanently registered with the RAIPPE.

During the real-time operation, for system security reasons, and as a last resort when no other means are available, the OS may, in application of the exceptional resolution mechanism, use the tertiary regulation available in the groups in pre-operational tests and require the participation of these production facilities in the resolution of the generation-consumption deviations. In addition, the OS may require in these conditions its participation in the complementary stress control service of the Transport Network, provided that the production facility is in a technical position to contribute to the voltage regulation.

P. O. -3.9 Hiring and backup management of additional power to upload

1. Object

The purpose of this procedure is to establish the process for the hiring and management of the additional power reserve to be uploaded, which may be necessary with respect to that available in the Provisional Viable Program (PVP) for ensure safety in the Spanish peninsular electricity system.

2. Scope of application

This procedure applies to the System Operator (OS) and to the Market Subjects (SM) holders of thermal installations of production of ordinary regime and special regime of a manageable nature.

In the content of this procedure, unless expressly stated otherwise, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the subjects scheduling unit holders.

3. Definitions

Power reserve to be compromised.

For the purposes of the provision of additional power reserve to be uploaded, the committed reservation is defined as the value of the additional power reserve to be uploaded to a programming unit as a result of the Additional power reserve hiring plus the one associated with your program in the PVP.

4. Service providers

Participate in this process, through the presentation of the corresponding offers, all subject holders of thermal units of ordinary regime and/or special regime of a manageable character:

(a) Having the corresponding rating of the System Operator, who will grant it to those programming units whose installation or set of physical facilities credit their corresponding technical capacity and operational for the delivery of the service in terms of the start-up and scheduling times required to meet the power reserve to be committed, and

b) That meet one of the following conditions in the Interim Viable Program (PVP):

Having a null program in each and every period that constitutes the daily programming horizon, or having only one power sale program in one or more of the first three time periods of the program horizon, in the form of a descending load ramp, associated with the process of decoupling of the unit, or having a program in the PVP, do not contribute in any of the periods that constitute the daily horizon of programming, reserve of power to increase to the system for being your program less than the minimum unit technician,

Having an energy sales program superior to the technical minimum of the unit in a certain mode of operation, with the capacity to contribute additional power reserve to up operating in other modes of operation, in the multi-axis combination cycles case.

4.1 Enabling units for service delivery: Production thermal installations must meet the following requirements for enabling:

(a) Dispose of the final registration in the corresponding section of the RAIPEE and, where appropriate, of the corresponding Resolution of the Directorate General of Energy Policy and Mines that authorizes the participation of the installation in the system tuning services of a potestative character.

b) Request submitted to the Participation System Operator in the additional power reserve service to be uploaded.

c) Integrating the production installation into a control center.

d) Communication to the OS of the additional information required for the providers of this service in the Operation Procedure establishing the exchange of information with the OS, and updating thereof when any variation occurs.

e) A satisfactory outcome of the analysis of the OS of the information specified in the operating procedure establishing the exchange of information with the OS, presented to the effect by the subject holder of the installation.

f) Verification that the programming unit provides an offering capacity for the provision of this service not less than 10 MW.

g) Verification that the programming unit has a start-up and programming time such that it allows the OS to make use of the power reserve to be allocated to that programming unit over the entire horizon of programming.

And all of the above regardless of the conditions that the higher-ranking rules of this procedure can set as a requirement to participate in the system tuning services.

For the acceptance of offers and consideration for all the effects of participation in the process of hiring additional power to move up from a production unit, the person responsible for the installation must count with the express authorization of the OS.

The OS may withdraw any of the ratings previously granted when it detects a lack of technical capacity for the provision of the service, the quality of the service provided does not meet the requirements required or does not receive the change or modification information in the production unit that might affect the delivery of this system tuning service.

5. Additional power reserve hiring process to be uploaded

5.1 Process Definition: After the Interim Viable Program (PVP) communication, the System Operator will determine the additional power requirements to be uploaded for each of the periods of the daily horizon of the programming as required, in accordance with the power reserve to be made available in the Provisional Viable Program (PVP) and, the power reserve to be raised in the Spanish peninsular electricity system as established in the the procedure by which the reserve requirements for the regulation are determined frequency-frequency.

5.2 Offer Presentation: Once communicated by the System Operator the additional power reserve requirements to be raised for the periods of the daily programming horizon where the hiring of Additional power reserve, the market subjects shall submit, within a maximum of 30 minutes, the tenders for the provision of additional power reserve to be uploaded to the system.

The offers will be presented for each of the programming units that are enabled, in addition to the conditions set for the service delivery.

The submitted bids will contain, per programming unit and programming horizon period, one or more simple offer blocks, in increasing order of price, with the value of the additional power reserve to be raised offered in MW, and its price in €/MW. A condition of indivisibility, applicable to a single block, may be established. The minimum reserve value of additional power to be raised per block shall be 1 MW. The minimum power reserve value to be raised in a programming period shall be 10 MW.

These blocks can be accepted independently. However, a single set of offer blocks can be defined in the offer in consecutive programming periods to be allocated together (block of type all or nothing).

The bids must respect the maximum prices that, if any, can be established and published by the competent authority in the field of electrical energy, prior to the report of the National Energy Commission.

The holders of the market, or their representatives, may send additional power reserve offers to the OS to be uploaded by default, in accordance with the procedure of the procedure for establishing the information exchanges with the OS.

The System Operator will verify that the holders of the market, or its representative, of the service delivery-enabled programming units comply with the requirement to submit bids for the service. the value of all your additional power reserve to be uploaded, provided that this service is called.

5.3 Offer allocation: The System Operator shall analyse the tenders received, validated in accordance with the criteria set out in Annex I to this procedure, and, in the event of any incompatibility with the programs established in previous processes, the allocation of the offer will be limited.

When assigning an offer to a technical constraint for security, the OS will set the program limitations that are necessary for security reasons, being taken into account in the allocation process. of offers.

The OS will assign valid offers received that, satisfying the requirements of additional power to raise together represent a lower cost, according to the algorithm specified in Annex II of this procedure.

When, as a result of the conditions of the tenders submitted, the maximum number of iterations of application of the algorithm specified in Annex II to this procedure has been carried out, it has been possible to allocate the total of the additional power to be raised required with a margin of +/-10%, the allocation process with an additional power value may be completed, in one or more periods, less than 90% of the requirement set and published.

The additional power reserve to be allocated, in each programming period, to each programming unit may be at most, equal to the difference between the maximum available power of the unit, and the value of its program in the PVP.

5.4 Communication of the results of the allocation: The OS will communicate the results of the process of allocation of bids for the hiring of additional power reserve to be uploaded to the market subjects providers of the service, in accordance with the schedules set out in the operating procedure establishing the programming of the generation.

This additional power reserve to be purchased by the OS shall be deemed to be firm, immediately after being communicated to the holders of the market, or to its representatives, acquiring the holder. or, where appropriate, the obligation to provide the additional reserve to be allocated in the time periods in which the tender submitted has been allocated.

The System Operator shall make available to market subjects the value of the additional power reserve to be raised and the marginal price of the power reserve to be allocated for each of the periods of the the programming daily horizon, in accordance with the procedure of operation whereby the exchange of information with the Operator of the System is established.

5.5 Failure and Claims Solution regarding the bid allocation process: Once the result of the offer allocation process for the additional power reserve hiring process is published, the subjects operators of the programming units may submit complaints to this process, within the time limit set in the operating procedure for which the programming of the generation is established, by means of the implementation of the Complaints made available for these purposes by the OS, and can advance the information the existence of this complaint, through telephone, fax or e-mail, and in any case the existence of a formal communication is necessary through the application of the information technology complaints, or by written means (fax or e-mail), for final consideration as a formal complaint.

The OS will manage, as soon as possible, these claims or any anomalies that could have been identified in the offer allocation process, proceeding with a new allocation process, in case the solution of the anomaly as necessary, provided that this is possible, with due respect to the maximum allowable time limits established and published by the OS, to ensure that the subsequent ones are not negatively affected operation programming processes.

6. Service delivery requirements

Depending on the start-up and scheduling times of the corresponding service provider units, the market subjects responsible for each programming unit will be required to participate in the different sessions of the Intra-day market to comply with the assigned service and to guarantee the provision to the system of the reserve of power to be compromised in the different programming periods. The programs thus established in the different sessions of the intra-day market will be considered as an effective provision of power reserve to be uploaded to the system.

Market subjects holding units to which the provision of additional power reserve has been allocated to them may be submitted to the OS, in the case of duly justified situations, to be indicated in their own request, to deal with another or other of its groups entitled to the commitment of power reserve to be acquired in all future programming periods from a specified period to be indicated also in the application. The OS shall appraise the application, if necessary, to transfer to the unit or units of programming the replacement of all the commitments of the power reserve provision to be made up of the replaced programming unit, in the periods of programming in which such substitution has been requested and accepted by the OS.

The programming units that have been assigned the additional power reserve provision to be uploaded to the system in a given programming period shall be required, provided that the System Operator calls the Management market for detours to be raised for that programming period, to perform a power reserve offer to be raised for that programming period by the difference between the value of the additional power reserve to be compromised and the value of its production programme which has been established by its participation in the different markets and system management processes.

7. Real-time tracking of service delivery

The System Operator will continuously analyze the power reserve requirements to be raised from the system, and in case of identifying a reduction of the additional power reserve requirements to be raised, with respect to the the volume already contracted, may, where appropriate, be subject to the reduction of the additional power reserve allocations to be increased, using in that case the order of economic precedence for the tenders submitted. This reduction of allocations will be communicated to the Market Subjects, replacing the new reduced allocations to the previous ones for the purposes of service delivery control.

The System Operator will check compliance with the assigned additional power reserve requirement to be uploaded by the active power telemetry registered in its real-time power control system and the records of the energy schedules, verifying the suitability of the response of the programming unit.

The System Operator will verify, as appropriate, based on the start and schedule time of the corresponding units, the modifications of the energy sales programs, in the different market sessions intra-day, of the generating groups to which the provision of the service has been assigned to them to ensure the provision of the additional power reserve to be uploaded to them.

The System operator will also check compliance with the requirement to present energy sales offers in the generation-consumption diversion management sessions, called by the Operator of the System according to the corresponding Operation Procedure, for a value equal to the difference between the maximum value of the power reserve to be committed and its production schedule.

8. Liquidation of the service

This section describes in general terms the main aspects of the additional power reserve hiring process to be uploaded on the system that have a direct impact on the liquidation of this service.

8.1 Service Provision Liquidation: Additional power reserve allocations to be uploaded will be valued at the marginal price of the additional power reserve offers to be allocated for each period of programming.

The OS will verify, for programming period, the actual and actual provisioning to the system of the additional power reserve to be allocated.

In the event that the power reserve to be uploaded to the system is less than the allocated reserve, the unfulfilled power shall be valued at the marginal price of the additional power reserve to be increased multiplied by a coefficient equal to 1,2.

The calculation of the payment entitlements and the payment obligations is defined in the operating procedure whereby the payment entitlements and payment obligations are established by the system adjustment services.

8.2 Distribution of costs arising from the provision of the additional power reserve service to be increased: The costs arising from the provision of the additional power reserve procurement service to be uploaded on the system imputed to the energy consumed within the Spanish electricity system and the sales units in proportion to their deviations from the programme, in accordance with the operating procedure establishing the charging rights and the payment obligations for the system tuning services.

9. Exceptional allocation mechanism

In the event that, in the case of emergency situations or for reasons of urgency, either because of the absence of offers, due to force majeure or otherwise of an unanticipated or controllable nature, the hiring of Reserve of additional power to be increased by the process provided for in this procedure, the OS may adopt the programming decisions it considers most appropriate to provide the system of the reserve of additional power to be required, supporting their subsequent actions to the affected operators and the NEC, without prejudice to the economic settlement of the same as applicable in each case.

Additional power reserve allocations to be increased by application of the exceptional allocation mechanism that has been required in each programming period shall be valued at a price equal to the resulting apply a KMAY capital ratio equal to 1.15, on the corresponding marginal daily market time price.

ANNEX I

Criteria for accepting and validating bids for additional power reserve hiring to be uploaded

The tenders submitted by the holders for the provision of additional power reserve to be uploaded shall be subject to the validation criteria set out in this Annex.

1. Checks applied in the tender receipt process

a) Only one offer per unit of programming for the additional power reserve to be raised will be admitted. In this way, if more than one offer is presented for a single programming unit, only the last offer received will be considered.

(b) The offer shall be sent by the holder of the market, or its representative, of the programming unit to which the offer corresponds.

c) The time period covered by the offer must be included in the daily programming horizon.

d) In each of the time periods for which the offer is submitted, the sum of the blocks that make up the offer must be equal to or greater than 10 MW.

e) Only one indivisible block per offer will be allowed, the block number 1 being mandatory for each programming period (lower price block). If these conditions are not met, the offer will be rejected.

f) Only one block of type all or nothing will be allowed per offer, the block number 1 being mandatory for each programming period. If these conditions are not met, the offer will be rejected.

(g) The bids shall respect the maximum prices which, if any, may be established and published by the Administration, after the National Energy Commission has submitted it.

h) Other additional checks as indicated in the Operation Procedure establishing the exchange of information with the OS.

ANNEX II

Offer Allocation Algorithm for additional power reserve hiring to be uploaded

1. Fundamental characteristics of the allocation algorithm

The main features presented by this offer allocation algorithm are as follows:

a) Iterative allocation process in which different application of the algorithm is performed until a valid solution is reached.

b) Indivisible and all-or-nothing-type offering blocks are supported.

(c) Marginalist market in which the settlement for the provision of the service in each programming period is determined by the price of the last offer partially or wholly allocated to cover the requirements in that period.

d) A margin is allowed in the allocation of bids (± 10% of the requirements) so that the valid allocation is considered when covering the requirements published within the range defined by this margin (90% <-> 110% of the published requirements).

2. Description of the operation of the algorithm

The procedure used in the offer allocation process is as follows:

1. For each programming period the offer blocks will be sorted in order of increasing prices.

2. For price equality, the blocks are sorted according to the following criteria:

a) First the divisible blocks and then the indivisible or all or nothing.

b) A equality of type (both divisible or indivisible or all or nothing), first the lowest power block.

c) A equality of all the above conditions first the block with the lowest order number in the offer (received first).

3. For each programming period of the daily horizon the blocks shall be assigned in the order indicated in points 1 and 2 above, using partially the divisible blocks if necessary, to cover the power requirements to be raised by the that period with a margin of ± 10%. In case of not being able to be satisfied the condition above with the blocks of a certain price will be continued with the blocks of the next price, until the allocation is completed.

4. When allocating the blocks per unit of programming and period will be considered:

(a) Maximum power constraints, associated with inavailabilities reported by the relevant market subject, or its representative, prior to the start of the allocation process.

b) Program limitations set by the OS for system security reasons.

c) The condition that the additional power reserve to be raised does not exceed the difference between the maximum available power of the group and its PVP program.

In the event that any of the offering blocks violate any of the above limits, it will be acted as follows:

d) Divisible block: The block will be truncated to the point where it stops violating the limit.

5. Indivisible block or all or nothing: The block will not be allocated in the programming periods in which the violation occurs. Once all the periods of the programming horizon have been processed, it shall be verified that the block of type all or nothing has been allocated in all the programming periods in which it applies that condition. In the event of non-compliance with this condition, all blocks of type all or nothing that would have been assigned will be unassigned. If once unallocated all these blocks are met the power requirements to be raised in all the affected programming periods with a margin of ± 10%, the allocation process will be finished. Otherwise, the following price blocks will be continued until the allocation is complete. This process will be repeated until a solution is reached, or a maximum number of (4) iterations. In the latter case the allocation process shall be completed by covering less than 90% of the power requirement.