Law 24/2013 of 26 December, of the Electrical Sector, establishes in its article 3.10, among the competences that correspond to the General Administration of the State, the one of regulating the terms in which the management is to be developed economic and technical system, by approving the market rules and the necessary instrumental and technical operating procedures.

For its part, Article 31 of the Royal Decree 2019/1997 of 26 December, for which the electricity production market is organized and regulated, establishes that the system operator and the National Energy Commission, Currently National Commission of the Markets and the Competition, may propose for approval by the Ministry of Industry, Tourism and Trade the procedures of operation of technical and instrumental character necessary to carry out the appropriate technical management of the system, who shall decide on the Commission's report.

Royal Decree 216/2014 of 28 March 2014 establishing the methodology for calculating the voluntary prices for the small consumer of electrical energy and its legal system of procurement determines in its provision In addition, the proposals for technical and instrumental operating procedures referred to in the preceding paragraph shall be accompanied by the report of the representatives of all the system subjects defined in the Article 6 of Law 24/2013, of December 26, of the Electrical Sector. This forecast was previously contained in the third additional provision of Royal Decree 485/2009 of 3 April 2009 regulating the implementation of the supply of last resort in the electricity sector, repealed by the aforementioned Royal Decree 216/2014 of 28 March 2014.

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.

One of the developed aspects is the design and implementation of a mechanism that allows the exchange of cross-border balance services, aimed at maintaining the balance between the generation and the demand, and to ensure a power available to System Operators to balance Systems in real time.

In this area, Red Electrica de España, S.A. as the operator of the system, submitted to the Secretariat of State of Energy dated 19 December 2013 a proposal for a new procedure for the operation of the cross-border exchange of balance-sheet energy and proposals for the adaptation of three operating procedures necessary for the implementation of the new mechanism, in particular the IP procedures. -7.3 tertiary regulation, P.O. -14.4 payment entitlements and payment obligations for the system adjustment services and P.O. -14.6 settlement of international exchanges not carried out by market participants. This proposal was accompanied by comments from market subjects and the response of the system operator to them.

The aforementioned proposal was sent to the National Commission of the Markets and Competition 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 for the production of electrical energy. The hearing procedure has also been carried out by the Commission through the members of its Electricity Advisory Board.

Law 3/2013, of 4 June, of the creation of the National Commission of the Markets and Competition, regulates in its article 7.1 the approval by the cited Commission of the methodology relative to the access to the infrastructures cross-border, including procedures for allocating capacity and managing congestion, in accordance with the regulatory framework for access to infrastructure and the functioning of the electricity production market and the criteria to be met. determine, as well as the methodologies relating to the provision of balancing services between systems managed by different system operators, which from the lowest cost point of view, in a fair and non-discriminatory manner, provide adequate incentives for network users to balance their production and consumption, according to the with the regulatory framework for the proper functioning of the electrical system.

The fourth transitional provision and the single repeal of Order IET/107/2014, of 31 January, for which electricity access tolls are revised for 2014, provide for the necessary aspects to adapt the Regulatory framework for the competences of the National Commission on Markets and Competition on the methodology for access to cross-border infrastructures, and procedures for allocating capacity and managing congestion in the Member States. international interconnections.

Having regard to Circular 2/2014 of 12 March of the National Commission on Markets and Competition establishing the methodology for access to cross-border infrastructures, including the procedures for assign capacity and manage congestion, as well as the methodology for the provision of balancing services between systems managed by different system operators.

Having regard to the report of the National Commission on Markets and Competition on the proposal for operating procedures for the implementation of a cross-border balance sheet energy exchange mechanism, dated 18 December March 2014.

In this report, it is noted that the proposed amendments to the operation procedure P.O. -14.4, inter alia: " this Commission considers the proposal to be appropriate, although it is recommended that the (i) a review of the provisions of the Treaty on European Union, the Council of the European Union, the Council of the European Union, the Council of the European Union, the European Parliament, the Council and the European Parliament, the Council and the European Parliament. service ".

View the Resolution of the National Commission of the Markets and the Competition dated March 25, 2014, for the approval of the Cross-Border Exchange of Balance Sheet Procedure.

This Secretary of State, prior to the report of the National Commission on Markets and Competition, resolves:

First.

Approve the operating procedures of the IP System. -7.3 tertiary regulation, P.O. -14.4 collection rights and payment obligations by the system adjustment services and P.O. -14.6 settlement of international exchanges performed by market participants, which are inserted below.

Second.

Modify paragraph 6.1 of the procedure for operating the system P.O. -3.2 Solution of technical restrictions, adopted by Resolution of 1 August 2013, of the Secretariat of State of Energy, for which the Amendment of the procedures for the operation of the Peninsular Electrical System (SEP), P.O. -3.1, P.O. -3.2, P. O 3.8 and P.O. 3.9, for adaptation to the change of the closing time of the daily market MIBEL at 12h00 CET, which is worded as follows:

" 6.1 Settlement 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, where applicable, in accordance with the programme limitations and, where applicable, as applicable, to energy measures. "

Third.

This resolution shall take effect from the day following that of its publication in the "Official Gazette of the State" and shall apply to the conduct of cross-border exchanges of balance-sheet energies which are carried out from 12 hours on 3 June 2014.

Fourth.

As of the date of application of this resolution, the procedures for the operation of the System P.O. -7.3 Tertiary Regulation, as approved by the Resolution of 18 May 2009, of the Secretariat of State of Energy, by which the operating procedures of the system 1.6, 3.1, 3.2, 3.3, 3.7, 7.2, 7.3 and 9 are approved for adaptation to the new electrical regulation, the P.O. -14.4 collection rights and payment obligations for the services of the adjustment of the system, approved by Resolution of 24 July 2012, of the Secretariat of State of Energy, by 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 the 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, and the P.O. -14.6 settlement of international exchanges not carried out by the market, adopted by Resolution of 28 July 2008, by the General Secretariat of Energy, by the the procedures for the operation of settlement services of system adjustment services 14.1, 14.3, 14.4, 14.6, 14.7 and 14.8 are approved and the procedure P.O. 14.5 charging rights and payment obligations for power guarantee is repealed.

Madrid, May 8, 2014. -Secretary of State for Energy, Alberto Nadal Belda.

INDEX OF OPERATION PROCEDURES

P. O. -7.3 Tertiary Regulation.

P. O. -14.4 Collection rights and payment obligations for the system adjustment services.

P. O. -14.6 Liquidation of international exchanges not carried out by market participants.

P. O. 7.3 "Tertiary Regulation"

1. Object.

The purpose of this procedure is to regulate the complementary service of tertiary regulation of the Spanish peninsular electrical system. It sets out the criteria for the following aspects:

Provision of the service.

Assignment of the capability.

Control and measure of the capability.

Service Economic Settlement Criteria.

2. Scope of application.

This procedure applies to the System Operator (OS) and the production and pump consumption facilities that are enabled for the provision of this service.

3. Definitions.

3.1 Tertiary regulation. -Tertiary regulation is a complementary service of a potential nature and offer, managed and remunerated by market mechanisms. It is intended to restore the reserve of secondary regulation which has been used, by adapting the operational programmes of the programming units concerned to production facilities and to installations of pumping consumption.

3.2 Tertiary regulation reserve. -A the effects of service delivery, the tertiary regulation reserve is defined as the maximum power variation to be raised or lowered which can be performed by a production unit or by a pump consumption unit within a maximum of 15 minutes, and which can be maintained for at least two consecutive hours.

At the global level of the Spanish peninsular electricity system, the total reserve of tertiary regulation is the set of tertiary regulatory reserves available in each and every programming unit corresponding to production facilities and pumping consumption facilities available in the Spanish peninsular electricity system.

4. Service providers.

All those programming units that obtain the corresponding enablement of the System Operator, who will grant it to those programming units whose installation or installation will be able to participate in this complementary service, will be able to participate in this complementary service. set of physical facilities credit their corresponding technical and operational capacity for the provision of the service.

4.1 Enabling units for service delivery. -Interested production facilities must meet the following requirements to obtain the enablement:

• Enrollment in the corresponding RAIPEE section.

• Request for participation in the service of adjustment of the tertiary regulation system.

• Integrating the production installation into a control center.

• Communication to the OS of the additional information required for the providers of this service in the Operation Procedure setting out the exchange of information with the OS and updating it when it is produce any variation.

• In the case of installations for the production of electricity from renewable sources, cogeneration or waste of a manageable nature for which it is required in accordance with the provisions of the legislation, the a corresponding resolution of the Directorate-General for Energy Policy and Mines authorising the participation in the system adjustment services of a potestative nature.

• Verification that the programming unit in which the production facility is integrated provides an offering capacity for the provision of this service not less than 10 MW.

• 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.

For the acceptance of tenders and consideration of all the effects of participation in the complementary service of tertiary regulation of a production unit, the person responsible for the installation must have the express authorization of the OS.

Production units are required to communicate and keep updated the information required by the OS in the relevant operating procedure to enable the proper functioning of the adjustment service. Tertiary regulation system.

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 any change or modification information that might affect the delivery of this system tuning service.

5. Determination and publication of tertiary regulatory reserve requirements.

The System Operator shall establish and publish the value of the required minimum tertiary regulatory reserve in the system for each programming period of the following day, in accordance with the operating procedure for which it is sets the reserve for frequency-power regulation.

6. Presentation of the tertiary regulatory offerings.

The holders shall make available to the System Operator the information relating to the tertiary regulation reserve corresponding to their programming units entitled to the provision of this service, both to rise and to fall, in the form of offers of reserve of tertiary regulation to be raised and/or to be lowered, within the time limits fixed in the procedure of operation by which the programming of the generation is established.

Thus, all programming units corresponding to production facilities or pump consumption facilities available to meet the requirement for the reserve of tertiary regulation will be required to submit each day, within the scheduling process of the next day's operation, an offer of all its available tertiary regulation reserve, both to be raised and to be lowered, for each of the next day's programming periods.

This information on tertiary regulation reserves provided by the subject holders of the programming units providing this service shall be consistent with the structural information reported by the relevant subject to the Operator of the System, in accordance with the operating procedure establishing the exchange of information with the System Operator, as well as with the particular real-time situation of each physical unit of production and of pumping consumption that integrate the respective programming units.

The programming units for production facilities or for pumping consumption facilities should offer, for each programming period, all of their available reserve of tertiary regulation, both to increase To be lowered, in MW, and the corresponding energy price, in €/MWh.

Should the System Operator detect that the reserve of tertiary regulation available in the planned programme does not permit the necessary requirements to be met, it shall, in application of the procedure by which it is establishes the solution of the technical restrictions, the coupling of additional thermal groups, in order to allow the required reserve of tertiary regulation in the Spanish peninsular electrical system.

The bid price for the tertiary regulation reserve allocation to be lowered has a repurchase price character of the equivalent unproduced energy.

The tenders must comply with the maximum prices which, where appropriate, can be established and published by the competent authority in the field of electrical energy, subject to a report from the National Commission of the Markets and Competition.

Tertiary regulation reserve offers may be limited in energy, so that their allocation over a given period may involve the cancellation or modification of the offer for subsequent periods. The limitation shall cover at least one programming period with the offer being cancelled in the following programming periods if it is allocated.

In Annex I to this procedure, the main criteria for validation of offers that are applied in the different phases of the allocation process are summarized.

7. Updating of tertiary regulation offerings.

The holders of the production units of the service will have to update their offers of tertiary regulation, within the day of the operation, provided that their reservation has been modified by one of the Following causes:

• Use of such capacity by allocations in the Intradiary Market (MI) or in the diversion management market.

• Unavailability of the production unit or pumping consumption.

• Secondary regulation band contribution.

• Other justified causes.

The period for updating the tertiary regulation offers for each programming period shall end 60 minutes before the start of each programming period, except in cases where the programming period The system operator shall communicate to the subjects, through the system operator information system, an extension of this offer update period, which in any case shall include a margin of at least 25%. minutes before the start of the next immediate programming horizon.

8. Allocation of tertiary regulation offerings.

Annex II to this procedure summarizes the main characteristics of the algorithm used for the allocation of tertiary regulation offerings.

As general criteria, the following should be noted:

• The System Operator will assign the service delivery with minimum cost criteria, taking into account existing offers at the time of their assignment.

• In case the allocation of a tertiary regulation offer originates a technical constraint on the system, it will not be allocated.

• When assigned to a programming unit corresponding to production facilities or to production facilities, an offer of tertiary regulation in a sense, in the event that subsequently, within the same time, the need to allocate reserve of tertiary regulation to the opposite is present, the latter will be allocated by the reduction, first, of the allocations that would have been made previously to the contrary, without affecting the marginal price of the tertiary regulation reserve in this new sense, provided that such partial or total deallocation is sufficient. The economic valuation of tertiary regulatory allocations to be raised and lowered shall be solely for the energy actually requested in the time interval at which the allocation has been maintained.

• The allocation of a tertiary regulation reserve offer in a given moment, maintained over a certain period of time, is equivalent to the implementation of a power redispatch on the previous energy programme of the the programming unit. This redispatch is calculated on the basis of the product of the power variation associated with the supply of tertiary regulation allocated by the time in which the allocation is maintained. This will determine the scheduled tertiary regulation energy as the result of considering a 15-minute power variation ramp from the time of the offer allocation, remaining after these 15 minutes, the final value of power without variation up to the final point of allocation or, where appropriate, until the moment of the allocation of the previously allocated tertiary regulation offer, in the event that this deallocation takes place before the end of the instant allocation end time initially set.

9. Solution of failures and claims relating to the offer allocation process.

Once the outcome of the tertiary regulation offer allocation process is published, the subject holders of the programming units will be able to submit claims to this process, using the Claims made available for these purposes by the Operator of the System, being able to advance the information regarding the existence of this claim through telephone communication, fax or e-mail, being necessary, in any case, the existence of an express formal communication through the application Claims management computing, or by a written means (fax or email), for final consideration as a formal complaint.

The System Operator 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, where the solution of the anomaly so requires, provided that this is possible, with due regard to the maximum allowable time limits set and published by the System Operator, to ensure that they are not negatively affected the subsequent programming processes of the operation.

10. Liquidation of the service.

The economic treatment of the complementary service of tertiary regulation is defined in the operating procedure whereby payment entitlements and payment obligations are established by the adjustment services of the system.

10.1 Liquidation of service provision. -Programming units corresponding to production facilities or pump consumption facilities enabled for the provision of the supplementary regulatory service tertiary, they may modify their energy programme for the allocation of tertiary regulation offers.

The tertiary regulation energy used will be valued at the marginal price of the tertiary regulation offers allocated in each programming period, distinguishing the reserve to be raised from the reserve to be lowered, and being calculated that marginal price in accordance with the mechanism specified in Annex II to this procedure.

In the event of a technical restriction in real time, programming for the resolution offers of tertiary regulation, these offers will not intervene in the formation of the marginal price of the energy use Tertiary regulation in the corresponding programming period.

The same settlement criterion shall apply to that tertiary regulation reserve which, notwithstanding the obligation of the submission of such an offer, has not been offered and for which the System Operator has required the use of the relevant tertiary regulatory reserve. The System Operator will inform the National Markets Commission and the Competition of these defaults in the offer of all tertiary regulation, both to upload and to lower, available in the unit.

10.2 Distribution of costs arising from the provision of the tertiary regulatory service.-The settlement of costs arising from the modification of the programme of programming units by the allocation of tenders Tertiary regulation shall be passed on in accordance with the criteria specified in the operating procedure establishing the payment entitlements and payment obligations for the system adjustment services.

11. Control of assigned service compliance.

The System Operator will check compliance with the requested Tertiary Regulation requirement through the active power telemetry registered in its real-time power control system, verifying the the suitability of the responses of the programming unit for the production or pumping consumption facilities, both in terms of variation of the power (power step), and of the maximum time (15 minutes) in that such power modification must take place.

12. Exceptional allocation mechanism.

In cases where, for reasons of urgency, the absence of offers by force majeure, or otherwise unanticipated or controllable, the allocation of tertiary regulation offers is not possible, the Operator of the System may adopt the programming decisions it considers most appropriate, for the use of the tertiary regulation reserve available in the system, subsequently justifying its actions to the subjects concerned and to the National Commission of the markets and the competition, without prejudice to the remuneration to which it would have been paid the provision of the service and the modifications of the programmes of the programming units concerned to production facilities or pumping consumption facilities that are necessary.

Tertiary regulatory energy allocations that, if any, can be applied by the OS by exceptional allocation mechanism will be valued:

For tertiary regulatory energy allocations to be uploaded: At a price equal to the result of applying a KMAY shift coefficient, of equal value to 1.15 on the marginal time price resulting from the allocations Tertiary regulation to be raised in that time or, failing that, on the marginal price of the day-to-day market.

For tertiary regulatory energy allocations to be lowered: At a price equal to that resulting from applying a KMIN minoring coefficient, of equal value to 0.85 on the marginal time price resulting from the allocations of Tertiary regulation to be lowered that have been carried out in that hour or, failing that, on the marginal price of the daily market.

ANNEX I

Tertiary Regulation Reserve Bid Validation Criteria

The tenders submitted by the subject holders of the programming units for the provision of the complementary tertiary regulation service shall be subject to the validation criteria set out in this Annex.

The participation in this process will be carried out through the sending of blocks of offers for different programming periods, constituting the offers as the groupings of the blocks offered for the same period of programming.

1. Validation of the offering blocks.

Only one offer per unit of programming for the sale of energy corresponding to generation units or per unit of programming for the purchase of energy for consumption of pumping for each date of call. In this way, if for the same call date more than once information is sent for the same programming unit, the last information will replace the previous one.

The offer must be sent by the subject holder of the scheduling unit to which the offer corresponds.

The time period covered by the offer must be included in the open call horizon in force at the time of receipt of the offer.

Only offers with a schedule date and period equal to or greater than the next programming period in progress, and covering all of the next day's programming periods, will be supported.

Each offer must respect the limitations of the maximum and minimum value of offer established and published in its case by the Operator of the System, in accordance with the National Commission of the Markets and the Competition. Power band offers outside this range will be rejected.

Each of the blocks of an offer of tertiary regulation to be raised, must respect the maximum prices which, if any, can be established and published by the organ of the competent administration in the field of energy The report of the National Commission on Markets and Competition.

In the case of programming units that integrate energy from installations belonging to the special regime, in each of the time periods for which the offer is submitted, the sum of the blocks, to be raised or to be lowered, that the compose must be equal to or greater than 5 MW.

If one or more blocks of a tertiary regulation offer have been allocated well in the tertiary regulation market, or for security to resolve a technical restriction identified in real time, only then will it be admitted after the receipt of new blocks that complement the offer, but not modifications of the already existing blocks at the time of the assignment.

In case of non-compliance with any of the validation criteria above, the offer will be rejected.

2. Pre-allocation checks for offers.

These checks are carried out by the establishment of the Tertiary Regulatory Reserve Offering Stairs to be uploaded and lowered, and always prior to the allocation of tenders, by requiring the consideration of such information as program limitations for security and inavailability of production units, which may have been modified from the time the offers were read.

The checks that are performed prior to the allocation of the offers are as follows:

• Non-violation of limits for security.

• No violation of limitations due to unavailability (communicated by the subject holder of the service provider programming unit or, failing that, introduced by the System Operator, after prior communication from the subject holder of that programming unit).

• Non-violation of the physical power limits of the group (only in the case of thermal groups and pumping units).

• Do not offer a power to lower your generation program, or for the programming units for power acquisition for pumping, power supply to go up higher than your pumping program.

• When an offer block violates any of these limits, the block will be truncated to the point where it stops violating the limit.

In this market, when the duration assignments are less than a programming period, when the validation is applied, the power profile of the programming unit is taken into account.

ANNEX II

Tertiary Regulation Reserve Offer Allocation Algorithm

1. Fundamental characteristics of the allocation algorithm.

The main features of this offer allocation algorithm are as follows:

The algorithm assigns power offerings (MW), not power.

The allocation process covers a particular programming period.

Supports duration assignments that are less than a programming period. In this case, the allocation horizon covers the period between the start and end minutes of the allocation set by the operator, or, until the end of the programming period in question, in the event that the operator does not explicitly set an allocation end-time other than the final instant of that programming period.

The marginalist market in which the price of the allocation of offers in each programming period is determined by the price of the highest price offer (or lower price, if it is a reserve of tertiary regulation). to be lowered) which has been allocated in a partial or total manner in that programming period.

A purely economic allocation process. The algorithm does not impose any constraints.

Indivisible offering blocks are not supported.

2. Description of the operation of the algorithm.

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

Build a list with all valid blocks that are offered in the programming period in question (Tertiary ladder to go up and down).

Ladder sorting by offer price:

The sort criteria depends on the type of offer. Thus, the blocks that offer the reserve of tertiary regulation to be increased are ordered from lower to higher price and those that offer reserve of tertiary regulation to lower are ordered from greater to lower price of offer.

When a pre-assignment was previously made, a tertiary regulation reserve allocation would have been performed in the opposite direction, preferably the previously allocated blocks. That is, to go in the opposite direction, you always deallocate what you previously assigned before you assign new offers in the opposite direction.

When multiple offer blocks exist at the same price, these are sorted by order of arrival of the offer files.

After the assignment is complete, the assigned power is converted into the corresponding power redispatch and the corresponding tertiary regulation power allocation is thus generated.

The price of the offer allocation depends on the offer type. Thus the allocations of the blocks that offer tertiary regulation to increase are associated to the marginal price of the reserve of tertiary regulation to increase, while those of the blocks that offer tertiary regulation to lower are associated to the price marginal of the tertiary regulation reserve to be lowered.

Although several sessions of the allocation of tertiary regulation reserve offerings are held within the same programming period, only a single marginal price of tertiary regulation will exist in that programming period. (if there have been offers of tertiary regulation offers to be raised in the programming period) and another of tertiary regulation to be lowered (if there has been an allocation in the programming period for which offers of tertiary regulation are to be lowered). These prices will be the extremes of the offer allocations made during the programming period (higher price offer, in the case of tertiary regulation to be increased, and offer of lower price, in the case of tertiary regulation to lower). It may be that there is no marginal price in some sense (going up or down), in the event that there has not been a need to allocate offers of such a ladder (tertiary ladder to rise or to go down), with only allocations and disallowances of offers on the opposite tertiary regulation ladder.

P. O. 14.4 Recovery rights and payment obligations for system adjustment services

1. Object.

The purpose of this procedure is to determine the payment entitlements and the payment obligations arising from the adjustment services of the system for the purposes of the settlement process, as set out in the Operation 14.1 and in the Operation Procedures relating to those services.

System tuning services include:

a. The resolution of supply security restrictions as set out in P.O. 3.10.

b. The resolution of technical restrictions of the PBF, the intra-day and real-time market established in the Operation Procedure 3.2.

c. The resolution of generation-consumption deviations established in Operation Procedure 3.3.

d. Secondary regulatory complementary services as set out in Operation Procedure 7.2.

e. Complementary tertiary regulation services as set out in the Operation Procedure 7.3.

f. The detours between the measurement in central bars and the program.

2. Scope of application.

This procedure applies to the System Operator and the Electrical Power Production Market Subjects.

3. General criteria.

3.1 Sign Criteria. The sign criterion adopted in the formulas of this procedure is as follows:

a. The production and import of energy have a positive sign. Energy consumption and export have a negative sign.

b. The energy to go up has a positive sign. Energy is defined to be raised as increases in energy production or import and decreases in energy consumption or export.

c. The energy to be lowered has a negative sign. Energy is defined to be lowered as decreases in energy production or import and increases in energy consumption or export.

d. The charging rights are a positive sign. Payment obligations have a negative sign.

3.2 Measures. -The measures referred to in the texts and formulas of this operating procedure will be understood as expressed in the following units:

a. Energy quantities shall be understood as expressed in MWh with the number of decimal places where the energy allocation or measurement is carried out in each case and up to a maximum of three decimal places.

b. Power magnitudes shall be understood as expressed in MW with the number of decimal places where the allocation or measurement of power is carried out in each case and up to a maximum of three decimal places.

c. Energy prices shall be understood as expressed in euro per MWh with the accuracy with which they are determined on each market.

d. Power prices shall be understood as expressed in euro per MW with the accuracy with which they are determined on each market.

e. The percentages will be understood already divided by 100.

f. Payment entitlements and payment obligations shall be understood as expressed in euro with two decimal places, where necessary, the necessary rounding.

3.3 Formulas. -The terms of the formulas of this operating procedure will be understood as referring to values of one hour, except express mention in another sense.

The term "PMD" in the formulas of this Operation Procedure means Daily Market Price.

In the distribution formulas, the minimum error rounding method will be applied to obtain rounded results that add up the amount to be distributed.

3.4 Terms. -In this procedure the term direct consumer refers to Direct Consumer in Market.

Marketing Programming Unit refers to the programming unit of a marketer for power purchase for delivery to its national customers on the peninsula.

Direct Consumer Programming Unit refers to the direct consumer programming unit for power purchase for consumption on the peninsula.

Acquisition Unit for Demand refers, in general, to the programming units of the previous two paragraphs.

4. Restrictions for security of supply and for technical restrictions of the PBF.

4.1 PBF modifications by security of supply and by security criteria.

4.1.1 Technical restrictions on PBF to be moved up in phase 1 to sales units.

4.1.1.1 Simple offer.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF with the use of the simple offer, because the complex offer will not be applicable, will give rise to a right of recovery of the unit u, for each b power block assigned, that is calculated according to the following formula:

DCERPVPVOS_{u, b} = ERPVPVOS_{u, b} × POPPVPVOS_{u, b}

where:

ERPVPVOS_{u, b} = Energy to be uploaded from the _{u unit's} u block assigned in phase 1.

POPPVPVOS_{u, b} = Offerited price for simple offer for b block of the u.

4.1.1.2 Complex Offering.-The allocation of power to be raised for resolution of technical constraints of the PBF with the use of the complex offer will result in a charge right of the unit u calculated according to the following formula:

DCERPVPVOC_u = ERPVPVOC_u × POPPVPVDAY_u

where:

ERPVPVOC_u = Energy to be uploaded from the u, unit in application of the complex offering.

POPVPVDIA_u = Applicable price for all hours of the day resulting from the application of the complex offering and obtained as follows:

POPVPVDIA_u = _{minimum (}IMPPVP_u, IMPPHF_{u)/ h} ERPVPVOC_{u, h}

Being IMPPVP_u and IMPPHF_u the daily revenue of the u unit that would result from the application of the complex offering to the program by constraints on the PVP and PHF respectively, as set below:

IMPPVP_u = NAF_{u, pvp} × PAF_u + NAC_{u, pvp} × PAC_u + NHES_{u, pvp} × PHC_u + ERPVP_u × PEC_u

where:

NAF_{u, pvp} = Number of cold daily starts scheduled in PVP.

PAF_u = Cold start price in complex offering.

NAC_{u, pvp} = Number of hot daily starts scheduled in PVP.

PAC_u = Hot start price in the complex offering.

NHES_{u, pvp} = Number of hours daily with power to go up for resolution of technical constraints of the PBF with use of the complex offering.

PHC_u = Price per hour in the complex offering.

ERPVP_u = Daily energy to be uploaded for the resolution of technical constraints of the PBF with the use of the complex offering.

PEC_u = Energy price in the complex offering.

It is considered that there is a scheduled start in PVP at hour h when in that hour there is no power allocated by PBF, there is power allocated by technical constraints to go up in phase 1 and in the previous hour there is no power allocated neither in PBF nor by technical restrictions in phase 1 to upload. If the block of previous and contiguous hours h with PBF zero program plus phase 1 to upload is equal to or less than four, the scheduled start will be hot. Otherwise it will be cold.

IMPPHF_u = NAF_{u, phf} × PAF_u + NAC_{u, phf} × PAC_u + NHR_{u, phf} × PHC_u + PHF_{u, phf} × PEC_u -IMDCBMI

where:

NAF_{u, phf} = Number of cold daily starts scheduled in PHF.

PAF_u = Cold start price in complex offering.

NAC_{u, phf} = Number of hot daily starts scheduled in PHF.

PAC_u = Hot start price in the complex offering.

NHR_{u, phf} = Number of hours per day with PHF greater than zero.

PHC_u = Price per hour in the complex offering.

PHF_{u, phf} = Daily PHF Energy on the day.

PEC_u = Energy price in the complex offering.

IMDCBMI_u = Sum of daily revenue in the first three hours on the daily market and bilateral contracts, calculated by marginal price valuation of the daily energy market of the PBF, and the daily balance of the Intra-day market sessions, phase 2 PBF restrictions and intra-day market restrictions.

If IMDCBMI < 0 then IMDCBMI = 0.

If IMPPHF_u < 0, then IMPPHF_u = 0.

A scheduled boot is considered to exist in PHF at hour h when in that hour there is no power allocated by PBF, there is power allocated by technical constraints in phase 1 to go up and in some previous hour there is no power assigned in PHF. If the block of previous and contiguous hours h with PHF zero program is equal to or less than four the scheduled boot will be hot. Otherwise it will be cold.

4.1.1.3 No offer or inadequacy of the existing offer.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF by exceptional mechanism of resolution will result in a right of recovery of the unit u that is calculated according to the following formula:

DCERPVPVMER_u = ERPVPVMER_u × 1,15 × PMD

where:

ERPVPVMER_u = Energy redispatched to upload by technical constraints of the PBF by exceptional resolution mechanism of the u.

4.1.2 Technical restrictions on PBF to be put up in phase 1 to units of purchase and export consumption.

4.1.2.1 Daily market transaction.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF to units of purchase and export consumption corresponding to the transactions of the daily market, shall be considered as a correction of the account entry in the Spanish production market equivalent to a charging right of the unit u, which is calculated according to the following formula:

DCERPVPC_u = ERPVPC_u × PMD

where:

ERPVPC_u = Energy to be uploaded for resolution of technical constraints of the u.purchase unit's PBF

4.1.2.2 Transaction associated with the execution of a bilateral contract with physical delivery. -The allocation of energy to be raised for the resolution of technical restrictions of the PBF to units of purchase of pumping and of consumption export of the transaction associated with the execution of a bilateral contract with physical delivery shall not result in any economic settlement.

4.1.3 Technical restrictions on PBF to be lowered in phase 1 to sales units.

4.1.3.1 Daily market transaction.-The allocation of energy to be lowered for the resolution of technical restrictions of the PBF to sales units corresponding to daily market transactions shall be considered as a rectification of the entry into account on the Spanish production market equivalent to a payment obligation for the unit u, calculated according to the following formula:

OPERPVPV_u = ERPVPVB_u × PMD

where:

ERPVPVB_u = Energy to be downloaded for the resolution of technical constraints of the u.sales unit's PBF.

4.1.3.2 Transaction associated with the execution of a bilateral contract with physical delivery in which the acquisition unit corresponds to a non-pumping national consumption. -The allocation of energy to be lowered for the resolution of technical restrictions of the PBF to sales units corresponding to transactions associated with the execution of a bilateral contract with physical delivery in which the unit of acquisition corresponds to a domestic consumption, excluding pumping, shall give rise to a payment obligation calculated according to the following formula:

OPERPVPCBN_{u, cb} = ERPVPCBN_{u, cb} × PMD

where:

ERPVPCBN_{u, cb} = Energy to be downloaded for resolution of technical constraints of the u unit's PBF by the bilateral contract cb.

4.1.3.3 Transaction associated with the execution of a bilateral contract with physical delivery in which the unit of acquisition corresponds to a pumping consumption or an export. -The allocation of energy to be lowered for the resolution of technical restrictions of the PBF to sales units corresponding to transactions associated with the execution of a bilateral contract with physical delivery in which the unit of acquisition corresponds to a pumping consumption or an export shall not give rise place for economic settlement.

4.1.4 Failures of starts or assignments to move up from phase 1.-Scheduled starts will be reviewed by checking that they have actually been performed according to the measures and the specific type of boot will be checked (cold or hot), taking into account that a cold scheduled start, when revised, may become a hot start according to the measures received, but not the other way round. For this purpose, the measures of the unit shall be taken into account in the last 5 programming periods of the day preceding the day of liquidation.

If there is a reduction in the number of starts or variation of the boot type, the collection rights calculated in section 4.1.1.2 will be recalculated using the number and type of starts actually made.

In the event that at all hours of the day with power scheduled to rise in phase 1, the energy measured for the unit is equal to or greater than the security programmed in the PVP, the calculated charging rights will be maintained and reviewed according to the preceding paragraph.

In the event that the one-hour measure is less than the security programmed in the PVP, a payment obligation or a charge duty calculated according to the following formula shall be entered:

OPEINCPVP_u = EINCPVP_u × (PMEDPVPS_u -PMD) if PMEDPVPS_u> PMD

DCEINCPVP_u = EINCPVP_u × (PMEDPVPS_u -PMD) if PMD > PMEDPVPS_u

where:

EINCPVP_u = Unfulfilled energy to be moved up in phase 1 of the u unit by discounting the power-driven default to be lowered by real-time constraints.

PMEDPVPS_u = The weighted average price of all scheduled power to be uploaded for the technical constraints resolution of the PBF in phase 1 of the uunit.

The unfulfilled power is calculated according to the following formula:

EINCPVP_u = MAX [-ERPVP_u, MIN (0, MEDRTR-PVP)]

where:

MEDRTR = MBC, if RTR ≥ 0 or if PVP ≤ PHF + TG.

MEDRTR = MAX (PBF, MBC) + MIN [PVP-(PHF + TG),-RTR] if RTR < 0 and

PVP≥ PHF + TG.

MEDRTR: a measure used for the calculation of the power failure to move up from phase 1, in which the energy-driven default is ignored for restrictions in real time.

MBC: measured in central bars, as set out in paragraph 13.2.

TG: sum of tertiary regulation power, deviation management, and real-time constraints.

RTR: Sum of power of constraints in real time.

4.1.5 Energy withdrawn by congestion at international border. -Energy withdrawal from the Operating Base Program to the units of sale or acquisition of transactions associated with a bilateral contract with physical delivery by Congestion at international borders shall not result in any economic settlement.

4.1.6 Restrictions on supply warranty.

4.1.6.1 Energy programmed in PBF. -In the event that one of the programming units of which are required to participate in the process of the resolution of restrictions by guarantee of supply as selling units has been programmed in the PBF, having been offered on the daily market in accordance with paragraph 3.1 of Annex II to Royal Decree 134/2010, and provided that the maximum production volume scheduled for the year has not been reached natural, the unit or a charge or a payment obligation which is calculated according to the formula shall be allocated to the unit next:

If PSGSu > PMD:

DCEPBFGS_u = EPBFGS_u x (PSGS_u -PMD)

If PSGS_u < PMD:

OPOPPBFGS_u = EPBFGS_u x (PSGS_u -PMD)

where:

EPBFGS_u = Energy programmed in the base program of operation to the unit u, being one of the required to participate in the process of solution of restrictions by guarantee of supply, having offered in the daily market in accordance with paragraph 3.1 of Annex II to Royal Decree 134/2010, and which does not exceed the energy value of the published updated operating plan, EPFGS_u, by the system operator.

EPBFGS_u = MIN (PBF_u, EPFGS_u)

PSGS_u = The unit or unit time price, corresponding to the unit cost of generation set for each central with the decimals that, if any, are set to be normalized in euro/MWh.

4.1.6.2 Energy programmed for the resolution of restrictions by guarantee of supply in the PBF.-The allocation of energy to be raised for solution of restrictions by guarantee of supply will give rise to a right of recovery that is calculates according to the following formula:

DCESGS_u = ESGS_u x PSGS_u

where:

ESGS_u = Power scheduled to be uploaded to the unit or in the supply warranty constraint resolution process.

PSGS_u = Unit or unit time price, corresponding to the generation unit cost set for each central.

4.1.6.3 Obligation to pay for non-compliance with the production of the programmed energy by guarantee of supply. -In the case that at all times of the day with energy programmed by guarantee of supply, the energy measured for the unit is equal to or greater than the scheduled unit, the collection rights calculated in accordance with the preceding paragraph shall be maintained.

In the event that the one-hour measure is less than the one scheduled for the supply guarantee in the PVP, a payment obligation or a charging right calculated according to the following formula shall be entered:

OPEINCGS_u = EINCGS_u × (PSGS_u -PMD) if PSGS_u > PMD

DCEINCGS_u = EINCGS_u × (PSGS_u -PMD) if PMD > PSGS_u

where:

EINCGS_u = Unfulfilled energy to be uploaded by supply assurance from the u.unit

EINCGS_u = MIN (0, MBC_u -EPPVPGS_u)

PSGS_u = Unit or unit time price, corresponding to the generation unit cost set for each central.

MBC_u = The measured output on central bars of the u.

EPPVGS_u = (EPBFGS_u + ESGS_u).

EPBFGS_u = Energy programmed in the base program of operation to the unit or with payment entitlements or obligations recorded under section 4.1.6.1.

ESGS_u = Power scheduled to be uploaded to the unit or in the supply warranty constraint resolution process.

4.1.6.4 Net energy increase managed in the markets for diversion management, tertiary regulation and intra-day market. -During the period of application of the fifth final Disposition of RD 1634/2011, since December 8 until 31 December 2011 inclusive, a right of recovery or payment obligation shall be entered into the net increase of the managed programme in the markets for the management of deviations, tertiary regulation and in the intra-day market, produced in a manner effective, and does not exceed the daily updated operation plan.

This energy will be valued at a price equal to the difference between the unit cost of generation and the average price resulting from all its transactions in the markets for diversion management, tertiary regulation and in the market Intraday, resulting:

DCEGSP48u = ESGSP48u x (PSGSu-PGSP48u) If PSGSu > PGSP48u

OPEGSP48u = ESGSP48u x (PSGSu-PGSP48u) If PSGSu < PGSP48u

where:

DCEGSP48u= Right of charge for net increase of managed program in the markets for diversion management, tertiary regulation and in the intra-day market.

OPEGSP48u = Payment Obligation for Net Managed Program Increase in Deviation Management, Tertiary Regulation, and Intraday Market markets.

ESGSP48u = Net program increase managed in the diversion management, tertiary regulation and intra-day market, with the right to the perception of the regulated unit cost, produced effectively, and that exceeds the daily updated operation plan.

PSGSP48u = The average unit time price or, resulting from all transactions in the diversion management, tertiary regulation, and intraday markets.

Net program augmentation, ESGSP48u, is calculated according to the following formula:

ESGSP48u = MIN [MAX (0, (EPFGSU-PVPu)), MAX (0, TERGDVMIu), MAX (0, (MBCU-PVPu))]

Therefore, ESGSP48_u > 0 if met:

SUM (MBCU) > SUM (PVPu) and SUM (EPFGSu) > SUM (PVPu) and TERGDVMIu > 0

and ESGSP48u= 0 if met:

SUM (MBCU) ≤ SUM (PVPu) or SUM (EPFGSu) ≤ SUM (PVPu) or TERGDVMIu ≤ 0

where:

TERGDVMIu = Net transaction balance in the intraday market, diversion management and tertiary regulation markets.

MBCU = Central bar metric, as set forth in section 13.2.

EPFGSU = The published daily operating plan energy.

PVPu = Scheduled Energy in the Interim Viable Program, following the result of technical constraints and restrictions by security of supply.

The average time price of the unit or, resulting from all transactions in the diversion management, tertiary regulation and intra-day market transactions is calculated according to the following formula for positive values of TERGDVMIu:

PSGSP48u = (EPRDS_{u, s} × PMPRDS_{s +} EPRDB_{u, s} × PMPRDB_s + ETERS_u × PMTERS + ETERB_u × PMTERB + Σ_s (EMIS_u × PMI_s + EMIB_u × PMIBGS_s)/TERGDVMI_u

Being the terms of price and energy the following:

PMIs = intraday market session s price s.

PMIBGS_s = min (PMI_s, PSGS_u) This price applies in case of repurchase on the intraday market so that if the repurchase price is higher than the unit cost of generation set for each central, no such entry is recognized.

EMISu, s = Energy scheduled to rise in intraday market s session.

EMIBu, s = Energy scheduled to be lowered in intraday market session s.

The rest of the terms are defined in the sections of this operating procedure relating to the management of deviations and tertiary regulation.

If the above price is negative with energy, ESGSP48u, positive, will be incorporated in the right to charge DCEGSP48u with its negative sign.

4.2 Reequilibrium generation-demand. -Energy assigned to lower, to obtain a balanced program in generation and demand, to units of energy sales corresponding to bilateral contracts whose demand has been reduced in the first stage of the process of resolution of technical restrictions of the PBF shall not result in any economic settlement.

The energy assigned to go up, to obtain a program balanced in generation and demand, to units of energy acquisition (consumption of pumping or, export) corresponding to bilateral contracts whose generation has been reduced in the first stage of the process of resolution of technical restrictions of the PBF, it shall not result in any economic settlement.

4.2.1 Energy programmed to move up in phase 2 technical constraints.

4.2.1.1 With simple offer presented.-The allocation of energy to be raised to solve a generation deficit and thus obtain a balanced program generation-demand will result in a right of collection of the unit u, for each b power block assigned, that is calculated according to the following formula:

DCERECOOSS_{u, b} = ERECOOSS_{u, b} × POECOS_{u, b}

where:

ERECOOSS_{u, b} = Energy in the _{u unit's b simple offering block assigned in phase 2.}

POECOS_{u, b} = Simple power supply price to be uploaded from the b block of the uunit, for the technical constraint resolution process.

4.2.1.2 No simple offer presented.

4.2.1.2.1 Acquisition units. -Energy assigned to rise to solve a generation deficit and thus obtain a balanced program generation-demand to acquisition units that have not presented the corresponding Energy supply to be raised for the process of resolution of technical restrictions, shall give rise to a charge calculated according to the following formula:

DCERECOS_u = ERECOS_u × 0.85 × PMD

where:

ERECOS_u = Energy to be uploaded to the u unit in phase 2, with no available offering.

4.2.1.2.2 Sales units. -Energy assigned to rise to solve a generation deficit and thus obtain a balanced program generation-demand to sales units that have not presented the corresponding simple offer of energy to be raised for the process of resolution of technical restrictions, shall give rise to a charge which is calculated according to the following formula:

DCERECOSOS_u = ERECOSOS_u × 0.85 × PMD

where:

ERECOSOS_u = Energy assigned to upload to the u, unit without a presented bid.

When allocations are made by exceptional resolution mechanism, it will result in a charging right that is calculated according to the following formula:

DCERECOMERS_u = ERECOMERS_u × 1,15 × PMD

where:

ERECOMERS_u = Energy assigned to upload to the u, drive without any available offers.

When all bids submitted are allocated, allocations by exceptional resolution mechanism will be made, resulting in a charging right that is calculated according to the following formula:

DCERECOMERS_u = ERECOMERS_u × 1,15 × PMD

where:

ERECOMERS_u = Energy assigned to upload to the u, drive without any available offers.

4.2.2 Energy scheduled to be dropped in phase 2 technical constraints.

4.2.2.1 With simple offer presented.-The allocation of power to be lowered to resolve an excess generation and thus obtain a balanced program generation-demand will result in a payment obligation of the unit u, by each b power block assigned, that is calculated according to the following formula:

OPERECOOSB_{u, b} = ERECOOSB_{u, b} × POECOB_{u, b}

where:

ERECOOSB _{u, b} = Energy to be lowered from the _b block of the simple offering of the u drive assigned in phase 2.

POECOB _{u, b} = The power supply price to be lowered from the b block of the uunit, for the technical constraint resolution process.

4.2.2.2 No offer presented.

4.2.2.2.1 Acquisition units. -Energy assigned to be lowered to solve an excess generation and thus obtain a balanced program generation-demand to units of acquisition when assigned all the offers presented, allocations by exceptional resolution mechanism shall be made, giving rise to a payment obligation calculated in accordance with the following formula:

OPERETRADE_u = ERETRADE B_u × 0.85 × PMD

where:

ERETRADE B_u = Energy to be dropped in phase 2 to the unit or, with no available offering.

4.2.2.2.2 Sales units. -Energy assigned to be lowered to solve an excess generation and thus obtain a balanced program generation-demand to sales units that have not submitted the corresponding energy supply To be lowered for the process of resolution of technical restrictions it shall result in a payment obligation calculated according to the following formula:

OPERECOSOB_u = ERECOSOB_u × 1,15 × PMD

where:

ERECOSOB_u = Energy to be dropped in phase 2 to the unit of sale or, with no offer presented.

4.2.3 Energy scheduled to be lowered for resolution of the imbalances between generation and demand after the resolution of supply-guarantee restrictions.-The allocation of scheduled energy to be lowered will result in an obligation Payment at the price of the daily market:

OPEBGS_u = EBGS_u x PMD

where:

EBGS_u = Scheduled energy to be lowered to resolve the imbalances between generation and demand after the resolution of supply warranty restrictions. This value is negative.

4.3 Over the technical constraints of the PBF.-The cost of the technical restrictions of the PBF (SCPVP) is calculated as the sum of all the payment entitlements and payment obligations of paragraphs 4.1.1 to 4.1.4 and of the paragraphs 4.2.1 and 4.2.2.

The cost of the technical restrictions of the PBF will be borne by the units of purchase, in proportion to their measured consumption to central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. outside the Spanish electrical system.

The payment obligation for each ua acquisition unit corresponding to the cost overpayment due to the technical constraints of the PBF is calculated according to the following formula:

OPSCPVPua = SCPVP × MBCua/Uua MBCua

4.4 Economic Balance of Supply Warranty Restrictions-The economic balance of the supply guarantee restrictions is calculated as the sum of all payment entitlements and payment obligations under paragraphs 4.1.6. and 4.2.3.

This balance shall be borne by the balance resulting from the difference between the income from the financing of the payments by capacity and the costs of its remuneration before its liquidation to the National Commission of the Energy. The remaining balance shall be considered as income or liquidable cost of the system for the purposes set out in Royal Decree 2017/1997.

5. Secondary regulation band.

5.1 Secondary throttling. -Power allocation for secondary throttling will result in a charge right for each u unit with allocated band that is calculated according to the following formula:

DCBAN_u = BAN_u × P_MBAN

where:

BAN_u = Secondary throttling band assigned to the u.unit

PMBAN = The marginal price of the secondary throttling band.

In cases where regulatory band is assigned by exceptional resolution mechanism, the price to be applied will be the result of the product of 1.15 for the marginal price of the band in the corresponding time period or, in its defect, for the maximum band price of the same time in the previous seven days.

Energy reissues to be raised or lowered to obtain the band allocated by exceptional resolution mechanism will, respectively, result in a charge or a payment obligation. The price to be applied will be the result of the product of 1.15, if it is energy to go up, or of 0.85, if it is energy to go down, for the marginal price of the daily market in the corresponding time period. The cost of this energy allocation will be the difference between the resulting amount and the result of valuing energy at the marginal price of the daily market.

5.2 Secondary regulation band variation by the operation of the secondary regulation in real time.

5.2.1 Penalization to the Regulatory Zone for cycles in which it remains in "off". -The cost of the penalty for cycles in which the zone z is in "off" will result in a payment obligation that is calculated according to the following formula:

OPOFF_z = OFF_{z ×} PMBAN × KI

being:

OFF_z =-KA_z × [RNTS + RNTB] × TOFF_z/TRCP

where:

PMBAN = The marginal price of the secondary throttling band.

KI = Coefficient of non-compliance published by the System Operator, prior to the authorization of the CNE. At the entry into force of this procedure, the value will be 1.5.

KA_z = Co-efficient of the z throttling zone in the system reservation.

RNTS = Total nominal reserve to be uploaded from the system.

RNTB = Total nominal reserve to be lowered from the system.

TOFF_z = Cycles in "off" of the zthrottling zone, with the exception of those that are per system operator indication.

TRCP = The number of active cycles of secondary throttling in the hour.

5.2.2 Bonification to the area of regulation by residual reserve superior to the allocated one. -The residual reserve bonus greater than that allocated will result in a collection right that is calculated according to the following formula:

DCRRS_z = RRS_{z ×} PMBAN × KB

being:

RRS_z = (RRSP_z + RRBP_z) _/TRCP

where:

PMBAN = The marginal price of the secondary throttling band.

KB = Bonus Coefficient that will be the same as the KI coefficient in paragraph 5.2.1.

RRSP_z = Cumulative value of the positive difference between the residual reserve to be raised by the regulation zone z and its rated power band to be assigned to the allocated amount obtained for the cycles in which the zone of throttling is active, inactive, or emergency.

RRBP_z = The cumulative value of the positive difference between the residual reserve to be lowered by the z regulatory zone and its rated power band to be allocated for the cycles in which the zone of throttling is active, inactive, or emergency.

5.2.3 Penalization to the buffer zone per residual reserve lower than the allocated. -The cost of the penalty for lower residual reserve, which has negative value for being RRSN_z and RRBN_z, will give rise to a payment obligation calculated according to the following formula:

OPRRI_z = RRI_{z ×} PMBAN × KI

being:

RRI_z = (RRSN_z + RRBN_z) _/TRCP

where:

PMBAN = The marginal price of the secondary throttling band.

KI = Default Coefficient that will be the same as the KI coefficient in paragraph 5.2.1.

RRSN_z = The cumulative value of the negative difference between the residual reserve to be raised by the z-regulation zone and its rated power band to be allocated to the cycles in which the regulatory zone is active, inactive, or emergency.

RRBNz = Cumulative value of the negative difference between the residual reserve to be put down by the z-regulation zone and its rated power band to be lowered allocated for the cycles in which the regulatory zone is in active, inactive, or emergency.

5.3 Total fixed cost of secondary regulation band allocation. -Total fixed cost of the secondary regulatory band shall be the sum of the payment entitlements and payment obligations of paragraphs 5.1 and 5.2 except for the energy redispatch derivatives as referred to in paragraph 5.1, in which the total fixed cost of the energy redispatches shall be part of the total fixed cost.

The cost of the secondary regulatory band (CFBAN) will be borne by the acquisition units, in proportion to their measured consumption of central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. outside the Spanish electrical system.

The payment obligation for each acquisition unit, ua, corresponding to the payment of the band is calculated according to the following formula:

OPCFBANua = CFBAN × MBCua/Uua MBCua

6. Technical restrictions of the intraday market.

6.1 Sale offers withdrawn for solution of technical restrictions on the appeal of the intra-day market or for the subsequent generation-demand rebalancing-withdrawal of an offer of sale of energy included in the appeal the intraday market shall result in a correction of the annotation in the Spanish production market equivalent to a payment obligation for the unit u calculated according to the following formula:

OPRTMI_{u, s} = ERVMI_{u, s} × PMI_s

where:

ERVMI_{u, s} = Energy removed to the u drive in the constraint solution process to the corresponding intra-day market s session.

PMI_s = The marginal price of the corresponding intra-day market s session.

6.2 Acquisition offers withdrawn for the solution of technical restrictions on the appeal of the intra-day market or for subsequent generation-demand rebalancing. -withdrawal of an energy purchase offer included in the An intra-day market appeal shall result in a correction of the entry into account in the Spanish production market equivalent to a charge for the unit u which is calculated according to the following formula:

DCRTMI_{u, s} = ERCMI_{u, s} × PMI_s

where:

ERCMI_{u, s} = Energy removed to the unit or in the constraint solution process to the corresponding s session of the intraday market.

PMI_s = The marginal price of the corresponding intra-day market s session.

7. Technical constraints in real time.

7.1 Real-time technical constraints to upload.

7.1.1 Technical constraints in real time to rise with tertiary offer.-The allocation of energy to be put up by real-time restrictions using the tertiary offer will result in a charging right for the unit u for each b power block that is calculated according to the following formula:

DCERTRT_{u, b} = ERTRTS_{u, b} × POTERS_{u, b}

where:

ERTRTS_{u, b} = Energy to be uploaded from the b block of the tertiary offering to be uploaded from the u drive by real-time restriction solution.

POTERS_{u, b} = Price offered for tertiary to be uploaded for power block b.

7.1.2 Real time technical constraints to upload with submitted offer for the technical restrictions solution process of the PBF. -Energy allocation to be uploaded for security in real time using the submitted offer For the process of solution of restrictions it will result in a charge right for the unit that is calculated according to the application of the simple or complex offer.

7.1.2.1 Simple offer.-The charging right of the u unit for each allocated b power block is calculated according to the following formula:

DCERTROS_{u, b} = ERTROSS_{u, b} × POSS_{u, b}

where:

ERTROSS_{u, b} = Energy to move up from the b block of the u unit's simple offering by real-time restriction solution.

POSS_{u, b} = Simple offer price to upload for power block b.

7.1.2.2 Complex Offering. -Payment entitlements or, where applicable, energy payment obligations limited by real-time restrictions to units that have submitted complex and application-related offerings are calculated as the following formulas:

DCRTROC_u = DCERRTROC_u + DCELTROC_u

Where:

DCERRTROC_u = ERTROCS_u x POCHORA_u

DCELTROC_u = Min (ELTROCS_u -ERTROCS_u, PHF_u) x (POCHORA_u -PMI_u)

If the amount of DCELTROC_u is negative, payment obligation will be logged.

ERTROCS_u = Power programmed to move up to in-time to the unit or by constraints in real time with complex offering application.

ELTROCS_u = Energy limited in time to the unit or by real-time constraints with complex offering application.

PHF_u = Energy of the last time program end of the unit or.

PMI_u = Average power price of the unit's final schedule schedule or in the time obtained by its participation in the intraday market.

POCHORA_u = The time price of the complex offer for the limited power at hour h, calculated according to the following formulas.

POCHORA_u = (NAF_u × PAF_u + NAC_u × PAC_u + HLIM × PHC_u + PECu × ENELIM)/ENELIM

NAF_u = The number of cold daily starts.

PAF_u = Cold start price in complex offering.

NAC_u = The number of hot daily starts.

PAC_u = Hot start price in the complex offering.

HLIM = Hours with power limited to the unit or by restrictions in real time.

PHC_u = Price per hour in the complex offering.

PECu = Power price in complex offering.

ENELIM = Power with limitation to be reduced by real-time constraints on the day with complex offering.

ENELIM = ERTROCS_u + Min (ELTROCS_u -ERTROCS_u, PHF_u)

The system operator shall publish the average hourly price of the limited power by restrictions in real time with complex supply of the set of producers and the daily coefficient resulting from dividing the energy total produced in the day between the total limited energy.

7.1.3 Technical constraints in real time to rise without offer.-The right to charge for the energy allocated on units that have not submitted an offer or that have exhausted the existing offer, is calculated according to the following formula:

DCERTRMER_u = ERTRMERS_u × 1,15 × PMD

where:

ERTRMERS_u = Power scheduled to be uploaded to the u drive by real-time constraint solution with no applicable offer.

7.1.4 Failures of starts or realtime assignments to be uploaded. -Scheduled starts will be reviewed by checking if they have been effectively performed according to the measures and will check the specific type of start (cold or hot), taking into account that a cold scheduled start when revised can be converted to a hot start according to the measures received but not the other way round. For this purpose, the measures of the unit shall be taken into account in the last 5 programming periods of the day preceding the day of liquidation.

If there is a reduction in the number of starts or variation of the boot type, the collection rights calculated in paragraph 7.1.2.2 will be recalculated using the number and type of starts actually made.

In the event that in all hours with energy limited to going down by constraints in real time, the energy measured for the unit is equal to or greater than the limited energy discounting the energy management of diversions and regulation The fee to be lowered shall be maintained as calculated and revised in accordance with the preceding paragraph.

In the event that the measure is less than the energy limited to being reduced by restrictions in real time, the value of the unfulfilled energy shall be determined and a payment obligation calculated according to the following formula shall be recorded:

OPEINCLTR_u = EINCLTRS_u x (PORTIME_u -PMD)

where:

EINCLTRS_u = Unfulfilled power of limitations by real-time constraints to upload from the u. Zero value will be taken if in time there is power of restrictions in real time to be lowered in the u. It will be calculated according to the following formula:

EINCLTRS_u = Max (-ELTRORS_u , min (0, MBCU-max (ELTRORS_u + TGB, 0₎ )

Where:

MBCU = measured in central bars, as set out in section 13.2.

TGB = sum of deviation management and tertiary regulation power to be lowered.

ELTRORSu = energy limited to getting down at the time to the drive or by restrictions in real time.

PORTIME_u = Average power price limited to going down by restrictions in real time.

PORTIME_u = (POCHORA_u x ENELIM + Σ_{b, of} (ERTR_{u, b, of} x POTR_{u, b, of}))/(ENELIM + Σ_pERTR_{p, u, b})

Where:

ERTR_{u, b, of} = energy to be moved up by real-time technical constraints assigned to the unit b block or for the of offer type (tertiary offering, simple offer of restrictions, no offer or offer exhausted).

POTR_{u, b, of} = price for technical constraints in real time to upload that applies to each b allocated power block of the u unit for the of offer type (tertiary offering, simple offer of restrictions, no offer or sold out).

7.2 Real-time technical constraints to download.

7.2.1 Technical constraints in real time to come down with tertiary offer. -Allocation of energy to be lowered for security in real time using the tertiary offer will result in a payment obligation to the unit u for each b power block that is calculated according to the following formula:

OPERTRT_{u, b} = ERTRTB_{u, b} × POTERB_{u, b}

where:

ERTRTB_{u, b} = Energy to be lowered from the b block of the tertiary offering to be lowered from the u drive by real-time constraint solution.

POTERB_{u, b} = Bid price for tertiary to lower for power block b.

7.2.2 Technical constraints in real time to come down with offer submitted for the process of solution of restrictions. -The allocation of energy to be lowered for security in real time using the offer presented for the process of Restrictions solution, will result in a payment obligation for the u unit for each allocated b power block, which is calculated according to the following formula:

OPERTROS_{u, b} = ERTROSB_{u, b} × POSB_{u, b}

where:

ERTROSB_{u, b} = Energy to be lowered from the b block of the simple offer to download from the u drive by real-time restriction solution.

POSB_{u, b} = Simple offer price to download for power block b.

7.2.3 Technical constraints in real time to go down without offer.-The obligation to pay for the energy assigned to go down on units that have not submitted offer or that have exhausted the existing offer is calculated according to the formula next:

OPERTRMER_u = ERTRMERB_u × 0.85 × PMD

where:

ERTRMERB_u = Power scheduled to be lowered to the unit or by real-time restriction solution, with no applicable offer.

7.2.4 Real-time technical constraints to be lowered to pumping acquisition units. -In the case of pump acquisition units the allocation of energy to be lowered for security in real time will result in an obligation of additional payment for the energy reserves generated in the upper glass of the pumping unit calculated according to the following formula:

OPERTRB_ucb = 0.7 × (ERTRTB_{u, b} + ERTROSB_{u, b} + ERTRMERB_u) × PMD

7.3 Overtime of the technical restrictions in real time. The cost of the technical restrictions in real time will be calculated as the difference between the sum of the receivables and the payment obligations of the paragraphs 7.1 and 7.2 and the amount of energy allocated by technical constraints in real time valued at the marginal price of the daily market.

The cost of the technical restrictions in real time (SCRTR) will be borne by the units of acquisition, in proportion to their measured consumption to central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. outside the Spanish electrical system.

The payment obligation for each ua acquisition unit corresponding to the payment of the cost over the technical constraints in real time is calculated according to the following formula:

OPSCRTRua = SCRTR × MBCua/Uua MBCua

8. International exchanges.

8.1 Support changes with price established for the same. -Support exchanges between systems performed by the System Operator through economic compensation for the energy supplied through the interconnections shall be entered for each interconnection in the System Operator account as the right to charge, if it is in the importing sense, and as an obligation to pay, if it is in the exporting sense.

The cost of the support exchanges shall be calculated as the difference between the receivables and the previous payment obligations and the amount of energy from the exchange valued at the marginal price of the daily market.

The cost of the exchange of support with established price will be borne by the units of purchase, in proportion to their measured consumption to central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. outside the Spanish electrical system.

The payment obligation for each acquisition unit, ua, corresponding to the payment of the cost over support exchanges (SCIA) is calculated according to the following formula:

OPPSCIAua = SCIA × MBCua/augua MBCua

8.2 Unpriced support exchanges. -Support exchanges to be performed by the System Operator by means of the return of energy will be valued at the marginal price of the daily market by making an annotation on a Time compensation for the purposes of settlement in accordance with the provisions of the PO14.6. The annotation shall be a collection right, if the exchange is an importer and a payment obligation, if it is in the exporting sense.

The time balance of this compensation account will be allocated to the acquisition units, in proportion to their hourly consumption measured at central bars, MBC_ua. for the purchase of pumping, the acquisition units corresponding to the supply of ancillary services of the production units and the acquisition units whose destination is the supply outside the Spanish electricity system.

8.3 Energy interchanges between electrical systems for system security. -Energy exchanges between electrical systems for safety, programmed by technical restrictions of the PBF or by technical constraints in time actual, will result in the following annotations according to the sense of the exchange:

Importer-wise exchange:

-Right of collection in the System Operator account for the amount agreed with the neighbor system operator.

-Payment obligation result of prior amount between the acquisition units in proportion to their hourly consumption measured to central bars, MBC_ua. Except for this allocation the units of the purchase of production units, the purchase units corresponding to the supply of ancillary services of the production units and the procurement units intended to be supplied outside the Spanish electricity system.

Exporter exchange:

-Payment obligation in the System Operator account equal to the sum of the collected receivables to the units programmed for this energy exchange in technical constraints of the PBF or real time, as set out in paragraphs 4.1.1 and 7.1.

8.4 Cross-border balance-sheet energy exchanges between electrical systems.-The cross-border exchange of balancing energy between systems performed by the system operator shall be valued at the price indicated in the (b) An hourly record shall be made for each interconnection in the system operator's account, for the purposes of its settlement in accordance with the provisions of the PO14.6.

8.4.1 Exchange of balance-sheet energies in the importing sense. -If the cross-border exchange of balancing energy has an import sense, a right of recovery shall be entered in each interconnection i shall be calculated by means of the following formula:

DCITB i = 3b (EIITBi, b x PEIITBi, b)

EIITBi, b = Bid block import energy b for cross-border exchange of balancing energy in the i pipeline,

PEIITBi, b = Offer block price b associated with the scheduled import in the cross-border balancing energy i pipeline.

8.4.2 Exporter balance sheet energy exchange. -If the cross-border exchange of balancing energy is in the exporting sense, a payment obligation shall be entered in each interconnection i shall be calculated using the formula next:

OPITB i = 3b (EITBi, b x PEEITBi, b)

EEITBi, b = Export energy of the bid block b corresponding to the cross-border exchange of balancing energy in the i interconnection.

PEEITBi, b = Price of the offer block b associated with the scheduled export in the cross-border balancing energy i for service.

9. Management of deviations.

9.1 Management of deviations to be uploaded. -Allocation of energy to be uploaded by the deviation resolution procedure results in a charge right for each u unit in the s session that is calculated according to the formula next:

DCPRD_{u, s} = EPRDS_{u, s} × PMPRDS_s

where:

EPRDS_{u, s} = Energy assigned to upload by the bypass resolution procedure to the u drive in the s.session

PMPRDS_s = The marginal price of the power allocation to be uploaded by the bypass resolution procedure in the s.session

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 1.15 for the maximum marginal price of the allocation of deviations to be raised in the sessions of the horao, in its defect, for the marginal price of the daily market.

9.2 Management of diversions to be downloaded. -Allocation of power to be lowered by the deviation resolution procedure results in a payment obligation for each unit in the s session that is calculated according to the formula next:

OPPRD_{u, s} = EPRDB_{u, s} × PMPRDB_s

where:

EPRDB_{u, s} = Energy assigned to download by the bypass resolution procedure to the u drive in the s.session

PMPRDB_s = The marginal price of the power allocation to be lowered by the bypass resolution procedure in the s.session

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 0.85 for the minimum marginal price of the allocation of deviations to be lowered in the sessions of the horao, in its defect, for the marginal price of the daily market.

10. Tertiary regulation.

10.1 Tertiary Regulation to be uploaded.-The allocation of energy from tertiary energy regulation to rise gives rise to a charging right for each unit that is calculated according to the following formula:

DCTER_u = ETERS_u × PMTERS

where:

ETERS_u = Tertiary energy assigned to upload to the u.unit

PMTERS = Marginal price of the tertiary assignment to be uploaded.

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 1.15 for the marginal price of tertiary regulation to rise from the time, in default, for the marginal price of the daily market.

10.2 Tertiary Regulation to be lowered. -The allocation of energy from tertiary energy regulation to lower gives rise to a payment obligation for each unit that is calculated according to the following formula:

OPTER_u = ETERB_u × PMTERB

where:

eterB_u = Tertiary energy assigned to download to the u.unit

PMTERB = The marginal rate of the tertiary allocation to be lowered.

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 0.85 for the marginal price of tertiary regulation to fall from the horao, in default, for the marginal price of the daily market.

11. Secondary regulation.

11.1 Secondary Regulation to be uploaded.-The contribution of secondary regulation power to be uploaded by each z regulatory zone results in a charging right calculated according to the following formula:

DCSEC_z = ESECS_z × PMSECS × CATS

where:

CATS = 1 if the tertiary ladder has not been exhausted to rise, otherwise, CATS will be equal to 1.15.

ESECS_z = Secondary throttling energy to be uploaded by the z.throttling zone

PMSECS = Marginal price of secondary throttling energy contributed to upload.

11.2 Secondary throttling to drop. -The secondary regulation power allocation to be lowered results in a payment obligation for each z throttling zone that is calculated according to the following formula:

OPSEC_z = ESECB_z × PMSECB × CATB

where:

CATB = 1 if the tertiary ladder has not been exhausted, otherwise CATB will be equal to 0.85.

ESECB_z = Secondary throttling energy contributed to download by the z.throttling zone

PMSECB = marginal price of secondary throttling energy contributed to download.

12. Reduction of the power consumption program by power reduction orders.

The reduction of the scheduled power consumption on the market for each acquisition unit due to power reduction orders shall be settled at the daily market price, as set out in Order ITC/2370/2007, of 26 July, regulating the service of management of the demand for interruptibility for consumers who acquire their energy in the production market.

In each hour with reduced power consumption of an acquisition unit, ua, due to power reduction orders, a charging right shall be entered for the au unit calculated according to the following formula:

DCSINT_ua = ERSINT_ua x PMD

where:

ERSINT_ua = High power to central bars of the time consumption reduction due to power reduction orders to consumers integrated into the ua unit.

PMD = Daily market marginal price.

13. Detours between measure and settlement program.

The detour will be calculated based on the measure on central bars (MBC) and the Schedule of Liquidation Schedule (PHL).

13.1 Schedule of Liquidation Schedule (PHL) of the u unit will be calculated as the sum of:

-End Time Program (PHF) Energy,

-Energies assigned in the Operating Schedule Program, excluding the energy from the reported deviations.

-Reduced consumption due to ERSINT_uapower reduction orders.

13.2 Measure on Central Bars. The measure on central bars of the u unit will be determined according to the following criteria:

a. The measure in the central bars of the production programming units, the pumping consumption programming units and the auxiliary service consumption programming units, will be the sum of the measures of the border points. allocated to the production facilities that comprise each programming unit.

In the case of the absence of measures of the production programming units, the value of the measure is considered to be zero. In the case of the absence of measures of the pumping consumption programming units, the value of the programme shall be considered as the value of the measure.

In cases where the measure of a border point collects the production of several production facilities, this value shall be apportioned in proportion to the individual measures or, in the case of the absence of an individual measure for the installation, proportionally to the value of the installed power.

b. The measure in central bars of import programming units shall be the energy allocated to the unit in the exchange programme at the international border agreed by both system operators.

c. The measure in central bars of export programming units shall be the energy allocated to the unit in the exchange program at the international border agreed by both system operators, plus the transport losses in the the case of exports by borders with countries with which no reciprocal agreement has been signed, according to the following formula:

MBC_uexp = PFI_uexp × (1 + CPER_frint)

where:

MBC_uexp = Central bar metric of the uexp.export programming unit

PFI_uexp = Energy assigned to the uexp export unit in the international border exchange program agreed by both system operators.

CPER_frint = Coefficient for the loss of the general high voltage access rate for the international border frint. The applicable value, in case the losses are applied, will be the one that corresponds to the voltage level 'greater than 145 kV' except in the interconnection with Andorra which shall be, if applicable, the one corresponding to the voltage level 'greater than 72,5 and not more than 145 kV'. At the borders with the countries with which the reciprocal agreement has been signed, the value shall be zero.

d. The measure in central bars of the marketing units and direct consumer units shall be calculated using the following formula:

MBC_uc =_{nt tata} [MPFC_{uc, nt, ta} × (1 + CPER_{nt, ta})]

where:

MPFC_{uc, nt, ta} = Sum of the measures of the energy consumed at the consumer border points to the uc marketer or direct consumer programming unit at the nt voltage level and the access ta. This value will be negative.

CPER_{nt, ta} = Loss coefficient for access contracts on supply points to consumers with voltage level nt and access rate ta and for the corresponding tariff period for the time in the access rate ta. This value will be positive.

These coefficients will be those set out in the regulations establishing the electricity tariff of each year to transfer the energy supplied to the consumers in their meters to energy supplied in bars (a) the effects of the liquidations provided for in Royal Decree 2019/1997 of 26 December 1997.

The tariff periods shall be those laid down in Article 8 of Royal Decree 1164/2001. For two-and three-term fares, the 23-hour day will be the first day of summer and the 25-hour day will be the first of winter. For the six-term fee, national holidays for each year will be published by the System Operator as set out in P.O. 14.1.

In the event that complete measures are not available, and therefore no measures are available for the marketing programming units and direct consumers the measure in the central bars of these units will be the resulting value of the following formula:

MBC_ua = PHL_ua + SALDOENE_ua

where:

PHL_ua = Acquisition Unit Liquidation Schedule Program for ua,excluding the program fee corresponding to the central bar consumption of the ua unit type 1 clients to which the potestative settlement established in P.O. 14.1 has been applied.

SALDOENE_ua = Assignment to the acquisition programming unit for demand ua of the settled power balance of the programs and the measures available in central bars (SALDOENE). The allocation shall be carried out in proportion to the Schedule of Liquidation Schedule of each unit according to the following formula:

SALDOENE_ua= SALDOENE × PHL_ua /_ua PHL_ua

e. The measure of the generic programming units is zero.

13.3 Price of deviations. -For the purposes of paragraph 13.5, the net balance SNSB of the energies to be charged and to be assigned shall be calculated:

− by the bypass resolution procedure,

− by tertiary regulation,

− by secondary regulation,

− by cross-system cross-system balancing energy services.

SNSB=_{u,(EPRDSu, s+ EPRDBu, s) +u,(ETERSu+ ETERBu) +zESECSz+ ESECBz) +i, b(EIITBi, b + EEITBi, b)}

13.3.1 Price of detours to rise. -They are defined as deviations to increase the deviations in the sense of greater generation and the deviations in the sense of less consumption.

If SNSB is negative, the time price of the deviations to be uploaded, for the purposes of paragraph 13.5, shall be calculated using the following formula:

PDESVS = minimum (PMD, PMPRTSB)

where:

PMPRTSB = weighted average price of the energy to be reduced as assigned by the deviation resolution procedure, by tertiary regulation and by secondary regulation, by cross-border balancing services according to the amounts recorded in accordance with paragraphs 8.4.2, 9.2, 10.2 and 11.2 respectively, rounded to two decimal places.

If there is no value for PMPRTSB or, if SNSB is non-negative, the price of the deviations to be uploaded will be the marginal price of the daily market.

13.3.2 Price of deviations to be lowered. -They are defined as deviations to lower the deviations in the sense of the lowest generation and the deviations in the sense of greater consumption.

If SNSB is positive, the time price of the deviations to be lowered, for the purposes of paragraph 13.5, will be calculated using the following formula:

PDESVB = maximum (PMD, PMPRTSS)

where:

PMPRTSS = weighted average price of the energy to be charged for the deviation resolution procedure, by tertiary regulation, by secondary regulation, by cross-border balancing services according to the amounts recorded in accordance with paragraphs 8.4.1, 9.1, 10.1 and 11.1 respectively, rounded to two decimal places.

If there is no value for PMPRTSS or if SNSB is non-positive, the price of the deviations to be lowered will be the marginal price of the daily market.

13.4 Deviation calculation.

13.4.1 Unseen from the Regulatory Zones. -The detour of each z throttling zone will be calculated using the following formula:

DESV_z =_u (MBC_u -PHL_u) x PUZ_{u, z} -(ESECS_z + ESECB_z)

where:

MBC_u = The central bar metric of the integrated u programming unit in the z.throttling zone

PHL_u = The u programming unit's Liquidation Schedule Program in the z.throttling zone

PUZ_{u, z} = The integration percentage of the u programming unit in the z.throttling zone

ESSEC_z = Secondary throttling energy to be uploaded by the z.throttling zone

EBSEC_z = Secondary throttling energy to be brought down by the z.throttling zone

13.4.2 Unintegrated programming units from non-integrated programming units. -The skew of each uprogramming unit, not integrated in the regulatory zone, of each demand acquisition unit, of each unit of import or export and generic units will be calculated using the following formula:

DESV_u = (MBC_u -PHL_u)

where:

MBC_u = High measure to central bars of each production or acquisition unit u, as set forth in section 13.2.

PHL_u = The time schedule cleared for each of each production or acquisition unit u, as set forth in section 13.1.

13.5 Collection rights and payment obligations for deviations. -For the purposes of determining the payment entitlements and payment obligations for deviations, the deviations will be calculated as follows:

-The deviation d of each throttling zone shall be the deviation calculated in paragraph 13.4.1

-The deviation d of each Liquidation Subject by the production activity under special regime shall be the sum of the deviations of its special regime programming units not belonging to the regulatory area. The deviation of each unit shall be that calculated in paragraph 13.4.2.

-The deviation d of each Liquidation Subject by the production activity under ordinary regime shall be the sum of the deviations of its ordinary non-regulatory zone programming units. The deviation of each unit shall be that calculated in paragraph 13.4.2.

-The deviation d of each Liquidation Subject for the marketing activity for domestic and acquisition customers for direct consumers will be the sum of the detour of its programming units and the deviations of those units of acquisition programming for domestic customers of other marketers with whom it has made bilateral contracts and is the marketer responsible for the system operator of its management, in virtue of the provisions of Article 20.6 of Royal Decree 2019/1997, as amended by the Royal Decree Decree 1454/2005, and in the P.O.14.1. The deviation of each unit shall be that calculated in paragraph 13.4.2.

-The deviation d for each of the international borders of each authorized subject for international export exchanges will be the sum of the deviations of their export programming units at each border. The deviation of each unit shall be that calculated in paragraph 13.4.2.

-The deviation d for each of the international borders of each authorized subject for international import exchanges will be the sum of the deviations of their import programming units at each border. The deviation of each unit shall be that calculated in paragraph 13.4.2.

-The deviation d of each subject by the generic programming units instrumentally enabled in the current regulations will be the sum of the deviations of these units. The deviation of each unit shall be that calculated in paragraph 13.4.2, considering a measure value equal to zero.

13.5.1 Positive Desired. -If the d deviation calculated as set out in the initial paragraphs of section 13.5 is positive, the price to be applied to the d detour will be the price of the detour to be uploaded, PDESVS, calculated as set out in paragraph 13.3. The amount shall be positive and shall be calculated using the following formula:

ECODESV_d = DESV_d × PDESVS

The amount will be supported by the programming units or regulatory zones that produce the d bypass based on the following criteria:

a. The u or zone z unit whose contribution to the d detour was negative (DESV_{uz, d < 0)} will have a payment obligation that will be calculated with the following formula:

OPPDESV_{uz, d} = DESV_{uz, d} × PMD

b. The u or zone z that has contributed positively (DESV_{uz, p > 0)} to the d detour will have a charging right that will be calculated with the following formula:

DCDESV_{uz, d} = DESV_{uz, d} × PMD + DESV_{uz, d} × DESV_d ×_{PDESVS-PMD)/u DESVPuz, d}

where:

_u DESVP_{uz, d} = sum of positive detours DESVP_{uz, d =} DESV_{uz, d > 0}

As a result of annotations on a. and b. The above is equality:

ECODESV_d =_uz DCDESV_{uz, d + OPPDESVuz, d}

13.5.2 Negative. -If the deviation d calculated as set out in the initial paragraphs of section 13.5 is negative, the price to be applied to the d detour will be the price of the detour to be lowered, PDESVB, calculated as set out in paragraph 13.3. The amount shall be negative and shall be calculated using the following formula:

ECODESV_d = DESV_d × PDESVB

The amount will be supported by the programming units or regulatory zones that produce the d bypass based on the following criteria:

a. The u or zone z unit whose contribution to the d detour has been positive (DESV_{uz, d > 0)} will have a charging right that will be calculated with the following formula:

DCDESV_{uz, d} = DESV_{uz, d} × PMD

b. The u or zone z unit that contributed negatively (DESV_{uz, d < 0)} to the d detour will have a payment obligation that will be calculated with the following formula:

OPPDESV_{uz, d} = DESV_{uz, d} × PMD + DESV_{uz, d} × DESV_d ×_{PDESVSB-PMD)/u DESVNuz, d}

where:

_u DESVN_{uz, d} = sum of the negative detours DESVN_{uz, d =} DESV_{uz, d < 0}

As a result of annotations on a. and b. The above is equality:

ECODESV_d =_uz DCDESV_{uz, d + OPPDESVuz, d}

13.5.3 Zero-Off. -If the deviation d calculated as set out in the initial paragraphs of paragraph 13.5 is zero, the economic amount will be zero. The payment entitlements and the payment obligations of the programming units producing the zero deviation shall be calculated according to the following criteria:

a. The u drive with positive detour (DESV_{u, d > 0)} will have a charging right that will be calculated with the following formula:

DCDESV_{u, d} = DESV_{u, d} × PMD

b. The u unit with negative deviation (DESV_{u, d < 0)} will have a payment obligation that will be calculated with the following formula:

OPPDESV_{u, d} = DESV_{u, d} × PMD

13.5.4 Annulment of the cost of diversion of exempt facilities. -Programming units that exclusively integrate special regime facilities completely exempt from the cost of deviations will have in each scheduling period a right to charge in respect of the cancellation of the cost of the diversion to be calculated according to the following formula:

DCDSVEX_u = Abs (DESVEX_u) x Abs (PMD-PREDESV_u)

where:

DESVEX_u = Unexempted from the u programming unit calculated as provided in paragraph 12.4.2 that will be positive or negative as appropriate to greater or less production than expected. The exemption is limited to deviations from the installed power, in the case of a programme exceeding that power.

PREDESV_u = Price of the payment entitlement or payment obligation of the u programming unit per deviation as provided in paragraphs 13.5.1, 13.5.2, and 13.5.3, result of the ratio between the amount scored and the power of the detour.

PMD = Daily market time price.

The sum of the receivables for cancellation of the cost of the deviations shall constitute the deficit of deviations exempt from the payment of the cost of deviations that will be settled from the balance of the surplus or deficit of valuation of the deviations of the paragraph 12.10 in which the sum of these receivables shall be included.

13.6 International Devios between Systems. -International deviations between systems are calculated as a difference between the measure at the border points with other electrical systems and the program agreed between the systems. The price of the detour as set out in paragraph 13.3 shall be valued as an entry into an hourly clearing account for settlement in accordance with the provisions of the P.O.14.6.

In each hour, international deviations will be added for each international interconnection.

DIR =_frint DIR_frint

where:

DIR_frint = International Desvio at Border frint,

If the sum of all international deviations from regulation is positive, a claim that will be calculated using the following formula shall be entered in the clearing account:

DCDIR = DIR × PDESVS

If the sum of all international regulatory deviations is negative, a payment obligation shall be entered in the clearing account that is calculated using the following formula:

OPDIR = DIR × PDESVB

The balance of this compensation account will be allocated to the acquisition units, in proportion to their hourly consumption, measured at central bars, MBC_ua. (a) the acquisition units, the acquisition units corresponding to the supply of ancillary services of the production units and the acquisition units whose destination is the supply outside the Spanish electricity system.

13.7 Coordinated Balance Sheet Actions with Other Systems. -Energy from coordinated balancing actions with other systems shall be valued from the Spanish system at the price of deviations set out in paragraph 13 that is applicable to the sense corresponding to the balancing action. An hourly annotation shall be performed for each interconnection in the System Operator account for use in accordance with the provisions of the P.O.4.1.

If the balance sheet action is in the importing sense (ABI), a collection right shall be recorded which shall be calculated using the following formula:

DCAB = ABI × PDESVS

If the balance sheet action is in the exporting sense (EBA) a payment obligation shall be entered in the following formula:

OPAB = EBA × PDESVB

13.8 Energy Closure. -In the closing of measures, the power closure in each hour, the REDRE, is calculated as the difference between the losses of transport and distribution and the calculated standard losses in accordance with the provisions of the second provision of Royal Decree 485/2009 of 3 April 2009, which regulates the implementation of the supply of last resort in the electricity sector.

RE = PRTD-_tant [MPFC_{uc, nt, ta} × CPER_{nt, ta}]

where:

PRTD = PT +_d PRD_d

PT = Lost transport network measures. This value will be negative.

PRD_d = Measures of the distributor distribution network d. This value will be negative.

The system power shutdown calculated according to the formula above will be valued at the daily market price.

The payment entitlements for positive closures and the payment obligations for negative closures shall be settled in the system operator's account. The resulting balance shall be considered as income or liquidable cost of the system for the purposes of Royal Decree 2017/1997 and as such shall be included in the liquidations of the regulated activities as provided for in the second provision of the Royal Decree 485/2009.

13.9 Allocation of surplus or deficit in the valuation of deviations. -As a consequence of the method of valuation of the deviations, the balance resulting from the set of payment entitlements and payment obligations in one hour (SALDOLIQ) will be a surplus, or, where appropriate, a deficit.

The surplus (SALDOLIQ < 0) will be distributed to the acquisition units, in proportion to their measured consumption to central bars, MBCua as a minorage of the costs of technical and band restrictions. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. outside the Spanish electrical system.

In case of surplus these units will have a right of collection in the time of adjustment that will be calculated with the following formula:

DCAJDV_u =-SALDOLIQ x MBC_ua /_u MBC_au

In the event that a deficit occurs in the hour (SALDOLIQ > 0) the previous units will have a payment obligation in the time of adjustment that will be calculated with the following formula:

OPOPJDV_u =-SALDOLIQ x MBC_ua /_u MBC_au

14. Programming failure of the generic programming units.

14.1 Obligation to pay for non-compliance with the zero balance obligation in PBF. -Following the mandatory report of the National Energy Commission, the non-zero balance of the energies of all the programming units generic of each market subject in the PBF will result in the following payment obligation:

OPUPGPBF= -abs (_{ugENPBFug) × PMD x 1.3}

where:

ENPBF_ug = Energy in PBF of the generic programming unit ug.

This payment obligation may be moderated in accordance with the circumstances of the case, taking into account the damage to the system and the diligence of the defaulting agent.

14.2 Obligation to pay for non-compliance with the zero balance obligation in the PHF. -Following the mandatory report of the National Energy Commission, the non-zero balance of the energies of all the programming units generic of each market subject in the PHF will result in the following payment obligation in each hour h:

OPUPPGPH= -abs (_ug ENPHF_ug) × PMD x 0.15 x NS

where:

ENPHF_ug = Energy in the last PHF of the ug.generic programming unit time

NS = Number of valid intraday market sessions for the time h.

This payment obligation may be moderated in accordance with the circumstances of the case, taking into account the damage to the system and the diligence of the defaulting agent.

14.3 Surplus for payment obligations due to programming failures.-The surplus generated by the payment obligations of paragraphs 14.1 and 14.2 shall be divided according to the method described in paragraph 13.9. Allocating the excess or deficit from the deviation rating.

15. Communication for the purposes of settlement of the equivalent premium.

The production facilities under special arrangements that have chosen the option of sale corresponding to Article 24.1 (a) of Royal Decree 661/2007, of 25 May will sell the premium to the National Energy Commission. equivalent.

As set out in Circular 4/2009 of 9 July, of the National Energy Commission, which regulates the request for information and the procedures for implementing the system of settlement of equivalent premiums, premiums, the incentives and additions to the electrical energy production facilities under special arrangements, the system operator shall communicate monthly to the National Energy Commission, the aggregate amount of the base for the settlement of the difference with the regulated tariff (Baldita) corresponding to the set of the installations of each representative and each holder who participates without a representative and who has chosen option (a) of Article 24.1 Royal Decree 661/2007.

The amount of the basis for settlement of the difference with the regulated rate, BALDITA, of each representative or holder rt in each month m shall be the sum of the amounts of the settlements to which the Article 30.1 and the amount of the impact of the cost of the diversion referred to in Articles 30.1 and 34 of Royal Decree 661/2007. The value of this sum is calculated according to the following formula:

BALDITA_{rt, m} = MEDPMD_{rt, m} + EMIPID_{rt, m}

Being:

MEDPMD_{rt, m} = The value of the time measures, MEAMID, of the net energy effectively produced by the i installations of the representative or rt holder in the m month valued at the market price journal, PMD, in every hour h:

MEDPMD_{rt, m} = Σ_{i, h} MEP_{, rt, h × PMDh}

EMIPID_{rt, m} = Value of the monthly gain or loss for the married energies in each session s of the intraday market of the hour h, EMI, by the i installations of the representative or owner rt in the mmonth, integrated into the up, programming unit resulting from the difference between the intraday market session price, PMI, and the daily market time price:

EMIPID_{rt, m} = Σ_{i, s, h} EMI_{i, rt, s, h}× (PMI_{s, h} -PMD_h) = Σ_{up, s, h} EMI_{up, rt, s, h} × (PMI_{s, h} -PMD_h)

16. Settlement of the scheduling units of the link between the peninsular electrical system and the Balearic electrical systems.

16.1 Technical constraints on the intra-day market. -Energy redispatches needed to resolve the identified technical constraints or for the generation-demand rebalancing will be settled at the price of the corresponding session of the intraday market.

16.2 Post-PHF program modifications. -Changes in the program of the post-link programming units to the various intraday market sessions will be settled at the market price journal.

The above annotations shall form part of the balance resulting from the set of payment entitlements and payment obligations in an hour that determine the balance (SALDOLIQ) referred to in paragraph 13.9.

16.3 Desvio of the program. -Net deviation of the power program of the power of the peninsular electrical system with the electric balance system will be calculated as a difference between the energy measured at the border point of the link with the peninsular system and the schedule of the net settlement of the scheduling units of the link and shall be settled at the price of the diversion set out in paragraph 13.3. The amount will be distributed proportionally between the programming units of the link according to your program.

The previous paragraph will not be applicable during the test period of the link. As set out in paragraph 2 of the second transitional provision of Royal Decree 1632/2011, the energy that runs through the link during the testing period shall be considered as losses of the peninsular electricity system. For this purpose it shall be settled at the daily market price and shall be entered in the system operator account as defined in paragraph 13.8. The traders of last resort shall be given a right of recovery to compensate for the amount of energy acquired on the market as set out in paragraph 1 of the second transitional provision.

The above annotations shall form part of the balance resulting from the set of payment entitlements and payment obligations in an hour that determine the balance (SALDOLIQ) referred to in paragraph 13.9.

16.4 Effects on the liquidation of the Balearic Islands.-The payment entitlements and payment obligations mentioned in 16.1, 16.2 and 16.3, as well as the energy settled, will be considered in the liquidation of the office of the Balearic Islands, as set out in paragraph 2 of the Annex to Royal Decree 1623/2011.

As a result of the sum of the amounts settled in the peninsular system and of the amounts settled in the issue to the dealers of last resort, the final cost of acquisition of the commercializers of Last resort in the Balearic system will be the one established in the additional provision 15th of Royal Decree 485/2009 of April 3, which regulates the implementation of the supply of last resort in the field of electrical energy.

P. O. 14.6 settlement of international exchanges not carried out by market participants

1. Object.

The purpose of this operating procedure is to establish the process of liquidation in the electricity production market of the monthly balance resulting from the execution of the following international exchanges. commercial:

-System-to-system regulation devices.

-Cross-system support exchanges.

-International interchanges of balancing energy between systems.

2. Scope of application.

This procedure applies to the System Operator.

3. System-to-system deviations.

The System Operator will carry an hourly compensation account in which the account entries set out in the P.O. 14.4 will be incorporated by the energy of the regulatory deviations between systems valued at the price of the deviation that is applicable.

The balance of this compensation account shall be allocated to the acquisition units, in proportion to their hourly consumption as measured at central bars. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. outside the Spanish electrical system. In the case of units of purchase of distribution, in the calculation of the measured consumption to central bars, consumption covered by the production of special rate facilities connected to one of the distributors shall be deducted. referred to in the 11th transitional provision of Law 54/1997.

4. Cross-system support exchanges.

The support exchanges established in P.O. 14.4, paragraph 8.1 between systems performed by the System Operator through economic compensation for the energy supplied, shall be entered in the System Operator account. The monthly balance of such exchanges shall be settled to the System Operator which shall be responsible for its settlement to the System Operators concerned.

The exchange of support established in P.O. 14.4, paragraph 8.2 between systems which the System Operator performs by means of a return of energy shall be valued at the marginal price of the daily market which shall be recorded in a Hourly compensation. The hourly balance of that account shall be allocated with the same treatment as for the system-to-system deviations.

5. International exchanges of balancing energy between systems.

The cross-border exchanges of balance-sheet energy between systems referred to in P.O. -7.6 and in paragraph 8.4 of the P.O. -14.4 and the balancing actions referred to in paragraph 13.7 of the P.O. -14.4 made between system operators will be logged into the system operator account.

The monthly balance of these exchange programs will be cleared to the system operator, who will be responsible in turn for the liquidation of the same with the operators of the corresponding electrical systems. interconnected.