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Unofficial translation APPENDIX C2 APPENDIX C2 MEASUREMENT REGULATION MEASUREMENT REGULATION NATURAL GAS TRANSMISSION CONTRACT - APPENDIX C2 Page 1 / 97

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Unofficial translation

APPENDIX C2APPENDIX C2

MEASUREMENT REGULATIONMEASUREMENT REGULATION

NATURAL GAS TRANSMISSION CONTRACT - APPENDIX C2 Page 1 / 81

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Unofficial translation

NATURAL GAS TRANSMISSION CONTRACT - APPENDIX C2 Page 2 / 81

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CONTENTS

ANNEX C2....................................................................................................................................................1MEASUREMENT REGULATION..............................................................................................................1CONTENTS...................................................................................................................................................2MEASUREMENT REGULATION..............................................................................................................4Article 1. Scope................................................................................................................................................................................4

METERING EQUIPMENT...........................................................................................................................5Article 2. Metering Equipment - Metering Current.........................................................................................................................5

Article 3. Operator Competences.....................................................................................................................................................5

Article 4. Metering Equipment Certification and Control...............................................................................................................5

Article 5. Metering Equipment Repair............................................................................................................................................5

Article 6. Measurement Precision and Uncertainty.........................................................................................................................6

Article 7. Measurement Storage Supporting Equipment.................................................................................................................7

MEASUREMENTS.......................................................................................................................................8Article 8. Magnitudes Measured – Measurement Units..................................................................................................................8

Article 9. Functionality Checks – Precision Testing......................................................................................................................8

Article 10. Measured Magnitude Adaptation..................................................................................................................................8

Article 11. Lack of Reliable Information.........................................................................................................................................9

Article 12. Information Record Keeping.........................................................................................................................................9

Article 13. User Access to the Metering Equipment.......................................................................................................................9

Article 14. Measurement Management..........................................................................................................................................10

Article 15. Measurement Reports..................................................................................................................................................10

Article 16. Natural Gas Quantities Certification...........................................................................................................................12

Article 17. Measurement Standards...............................................................................................................................................17

Article 18. Analysis Standards (Gas Quality)................................................................................................................................17

Article 19. Sampling Standards.....................................................................................................................................................17

MEASUREMENTS - CALCULATIONS - CORRECTIONS....................................................................18Article 20. Measurements & Calulations.......................................................................................................................................18

Article 21. Correction Methods.....................................................................................................................................................18

Article 22. Calculation Methods....................................................................................................................................................18

METERING INSTRUMENTS....................................................................................................................22Article 23. General.........................................................................................................................................................................22

Article 24. Metering Instrument Definitions and Types................................................................................................................22

Article 25. Main Metering Instrument Groups..............................................................................................................................23

Article 26. Temperature - Thermometers......................................................................................................................................23

Article 27. Pressure – Pressure Gauges.........................................................................................................................................24

Article 28. Flow Meters.................................................................................................................................................................25

Article 29. Gas Chromatographs...................................................................................................................................................27

METERING PROCEDURES......................................................................................................................28Article 30. NGTS Metering Station Equipment............................................................................................................................28

Article 31. Measurement Procedures.............................................................................................................................................28

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Article 32. Exit Points....................................................................................................................................................................29

CALIBRATION..........................................................................................................................................30Article 33. Equipment Calibration.................................................................................................................................................30

Article 34. Metering Equipment Calibration Frequency...............................................................................................................31

Article 35. Metering Equipment Calibration Procedures..............................................................................................................31

TABLES......................................................................................................................................................34TABLE Ι. Metering Equipment Checking.....................................................................................................................................34

TABLE ΙΙ. Metering equipment calibration procedures................................................................................................................34

TABLE ΙΙI. Calibration Equipment Standards..............................................................................................................................35

TABLE IV. Custody Transfer Instruments - (Measurement) Precision Standards - Procedures, Methods.................................36

TABLE V. NGTS Measurement Regulation Applicable Standards..............................................................................................38

TABLE VI NGTS Exit Points.......................................................................................................................................................40

TABLE VIΙ Future NGTS Stations...............................................................................................................................................40

FORMS........................................................................................................................................................41DAILY NG QUANTITY AND MEASUREMENT CHARACTERISTICS PROTOCOL AT ENTRY POINT........................42

DAILY NG QUALITY COMPOSITION PROTOCOL AT ENTRY POINT.............................................................................43

MONTHLY NG QUANTITY AND MEASUREMENT CHARACTERISTICS PROTOCOL AT EXIT POINT.....................44

MONTHLY NG QUALITY COMPOSITION PROTOCOL AT EXIT POINT..........................................................................45

APPENDIX 2...............................................................................................................................................47ENTRY POINTS.........................................................................................................................................50EXIT POINTS.............................................................................................................................................52

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MEASUREMENT REGULATION

Article 1. Scope

The scope of the Measurement Regulation includes:

Natural Gas quantity metering and certification procedures

the description of the procedures and methods used to control and calibrate Metering Equipment, including the Precision Standards considered in each case;

a brief description of the individual instruments of Metering Equipment, including their type and specifications;

the terms and conditions under which the volume, Calorific Value, quantity and/ or any other characteristic of the Natural Gas delivered to an Entry Point or received at an Exit Point by the User are established in case of Metering Equipment fault or failure to provide measurements;

the procedures and conditions for settling disputes arising between the Operator and the User with regard to issues concerning quantity measurements, Calorific Value calculations and the quality of the Gas delivered and/ or received.

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METERING EQUIPMENT

Article 2. Metering Equipment - Metering Current

The Metering Equipment includes all metering and analysis instruments used by the Operator in determining the quantity and analyzing the quality of the Natural Gas delivered to an Entry Point and received at an Exit Point of the NGTS.

The Metering current includes the Metering Equipment for measuring the flow of uncorrected or corrected volume and the entry of Natural Gas quality analysis data (composition), on a case to case basis, for energy calculation purposes. Especially for Bus Natural Gas Refueling Stations (BNGRS), the Metering current comprises a mass metering device using the Coriolis force method.

Article 3. Operator Competences

The Operator is responsible for supplying, installing, testing, maintaining, checking and certifying the compatibility of the Metering Equipment as per the specifications listed in Tables ΙΙΙ, ΙV and V of this Measurement Regulation.

Article 4. Metering Equipment Certification and Control

1. Each new Metering Equipment element shall undergo precision testing and functionality checks as provided for in Article 9 hereof.

2. Any Metering Equipment instruments that go out of service due to fault shall be certified anew prior to being reconnected for use.

3. The Operator shall run regular checks on the Metering Equipment at the frequency established in Table I.

4. Each check of the Metering Equipment shall be run by the Operator or its authorized representative. The User shall be entitled to be present during Metering Equipment checking if the User requests so in writing. The User may report to the Operator any remarks regarding Metering Equipment Checks. In no case may the User tamper with the Metering Equipment in any way.

5. Provided the Metering Equipment meets the specifications of Article 3 (1) hereof, the Operator shall issue the respective check certificate established in Table Ι. The check certificate shall be notified to the User.

6. Within five (5) days from the foregoing notification the User shall lodge with the Operator any objections regarding the correctness of the information in the certificate, which objections shall be considered in accordance with the terms on dispute settlement laid down herein.

7. Besides regular checks, the User may request from the Operator in writing Metering Equipment checks at each Entry or Exit Point included in the Transmission Contract. The check shall be run by the Operator following the User’s timely notice in writing, who shall be entitled to be present. If the check results in that the Equipment operates within the predefined precision limits, the User shall incur the cost of the check, otherwise such cost shall be incurred by the Operator.

Article 5. Metering Equipment Repair

The Operator shall be required to immediately set, repair or replace any Metering Equipment instrument or other element which has suffered damage or fault or has ceased to operate, leading to non-compliance of the Metering Equipment with the foregoing specifications.

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Article 6. Measurement Precision and Uncertainty

1. Definitions - CalculationsThe Precision and Uncertainty of measurements are defined as follows:Measurement Precision shall mean the proximity of a measurement to the mutually accepted reference value for the magnitude measured. The term “precision” refers to uncertainty.Uncertainty shall mean the quantitative ability of a metering system to give a value for a magnitude as close as possible to the real value. Under ISO 5168 uncertainty is defined as “an estimate characterizing the value range within which the real value is found”. The real value shall mean the ideal value which is assumed to exist and which could have been known had all sources of error been eliminated. Uncertainty can be random and systematic. A random measurement error shall be the deviation of a random measurement from the average value for the magnitude measured. Random errors shall mean those errors that provide the observed fluctuation of repeated measurements taken apparently under the same conditions.A systematic measurement error shall mean the deviation of the average measurement from the real value. Systematic errors shall be those that are introduced as a result of imperfections in the metering instruments, their calibration or the metering technique used. Systematic errors are characterized by their property to move towards one direction.Therefore, for a small random error (small deviation), the precision of a measurement is considered to be high, whereas for a big random error (big deviation) the precision of a measurement is considered to be low. The random Uncertainty, eR , of a measurement is defined as ±tσ , where σ the standard deviation of the measurement and t the statistical value corresponding to the probability selected. To establish the value for t we have used the “Student’s t test” method, and such value is equal to 2 for a confidence level of 95%. Hence random uncertainty is obtained from the following formula: (eR)95=±2σ. Standard deviation is

obtained from the formula σ= (1) where:

Ν is the number of measurements takenis the average value of individual measurements for a variableis the value of one measurement for one variable (magnitude measured), e.g. Pressure P, Temperature

Τ, Energy Ε, etc.

Systematic Uncertainty, , (bias) shall be the upper limit of the systematic error. Hence the total Uncertainty for measurement U is obtained, under the international ISO 5168 (Table V) standard, from the formula U= (2) and expresses the interval (value range) within which it is probable that the real value of the magnitude measured fluctuates with a confidence level of 95%.

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2. Individual Uncertainties of the metering systemThis article refers to the individual uncertainties regarding the magnitudes measured, which contribute to the overall uncertainty in the Energy of each metering system.Uncertainty studies are classified in terms of the structure of the calculations of the magnitudes measured depending on the meter type, as detailed below:

Α. System uncertainty in Energy for turbine meters Volume measurement uncertainty Pressure measurement uncertainty Temperature measurement uncertainty Uncertainty in the calculation of the compressibility factor and mathematical operation error Gross Calorific Value (GCV) measurement uncertainty

B. System uncertainty in Energy for orifice meters Differential pressure measurement uncertainty Pressure measurement uncertainty Temperature measurement uncertainty Orifice diameter uncertainty Metering current pipe diameter uncertainty Uncertainty regarding orifice diameter to pipe diameter ratio Discharge coefficient uncertainty Expansibility factor uncertainty Density measurement uncertainty (also under reference conditions) Gross Calorific Value (GCV) measurement uncertainty

The overall uncertainty U of the system with regard to Energy is calculated using formulas (1) and (2) above in accordance with a relevant uncertainty study conducted by the manufacturing company.For both types of meters, orifice and turbine meters, ISO 5168 is used in conjunction with ISO 5167.1991 (Table V).In accordance with this article, the magnitudes measured (pressure, differential pressure, temperature, flow volume, gross calorific value, energy, calculations, etc.) are considered acceptable when the measurement readings are within the acceptable error limits for the magnitude measured, in accordance with the relevant uncertainty study or the precision data for the metering equipment provided by the manufacturing company. Where the measurement readings are within the acceptable error limits, then the magnitude measured is adjusted as indicated in Article 10 “Measurement Management”. Uncertainty studies are revised when part of the existing metering equipment changes or where the international standards referring to the methodology of their calculations undergo radical changes.

Article 7. Measurement Storage Supporting Equipment

The magnitudes measured and calculated (qualitatively and quantitatively) by the metering equipment are stored in electronic format in supporting storage equipment. Such storage units are located either in the supervising computers or volume correctors (PTZs) of metering stations. The measurement files generated are stored in the supporting equipment at least until the signature of the respective monthly report.

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MEASUREMENTS

Article 8. Magnitudes Measured – Measurement Units

At the NGTS Entry and Exit Points constant measurements are taken for the magnitudes that regard the Natural Gas quantity transmitted (mass, volume flow, density, pressure, differential pressure, temperature), while in general sampling measurements and/ or analysis are run at regular time intervals for magnitudes regarding the quality characteristics of the Gas. Where this does not apply, information is obtained regarding Gas quality characteristics from neighboring NGTS Entry or Exit Points.

Table IV lists all measured or calculated magnitudes.

The measurement units for such magnitudes are listed in the same table, which lists among others custody transfer, international standards and measurement precision.

The definitions of measurement units are given in the respective international standards, Law 3428/2005 (Government Gazette Issue No. 313/27.12.2005), as well as in the Transmission Contract.

Hourly, daily and monthly measurement information is kept for each Entry and Exit Point.

Article 9. Functionality Checks – Precision Testing

The Metering Equipment undergoes both functionality checks and precision testing.

Functionality checks shall mean all those checks run by the Operator's personnel at regular intervals aiming to ensure the satisfactory operation of the Metering Equipment and in general of the supporting equipment of metering stations.

Alarms received at the Operator’s Supervisory Control and Data Acquisition (SCADA) System and which are due to abnormal states of the Metering Equipment and/ or the metering station shall constitute grounds for running checks, including but not limited to emergency functionality checks.

Precision Testing shall mean those checks run by the Operator’s specialized personnel following information received by the User at regular intervals for which provision is made in the Measurement Regulation or the instructions of the equipment manufacturers or agreed upon with the User. Unscheduled precision tests shall be following a fault or suspicion of fault in the Metering Equipment. The User shall be entitled to be present during Metering Equipment Precision Testing.

The reference information for all checks and tests shall be kept by the Operator for the period provided for in Article 12.

The Tables in Appendix 2 list all the information for the Metering Equipment elements of the NGTS metering stations. Metering stations are sorted at Entry and Exit Points. The same table also lists the anticipated precision for energy metering for each station as has been calculated following relevant uncertainty studies (Article 6), which take account of the installation details (listed in the same table) and the recorded permissible error limits of individual instruments (overall possible error). Such limits and overall uncertainties for the Metering Equipment in conjunction with the uncertainty of the (working) reference standards establish the limits above which arrangements shall be necessary during the calibration of the Metering Equipment performed after Precision Testing.

Article 10. Measured Magnitude Adaptation

1. Where following a check the precision of the Metering Equipment at an Entry or Exit Point is found to be outside the permissible error limits, the value of the respective Measured Magnitude, as this

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has been measured shall be adapted by use of calculations, the algorithms of which are based on international standards (Table V) to minimize the Metering Equipment error.

2. Where para. 1 hereof applies, the erroneous values of the Measured Magnitude throughout the period during which it is demonstrated that the precision of the Metering Equipment had been outside the permissible limits, shall be replaced by the corrected values.

3. If it is not found with certainty that the date of commencement of the period described in point 2 above, as such shall be considered either the first day of the second half of the period from the last check on the Metering Equipment or the date of the last admissible measurement based on the Delivery - Offtake Reports or on the last admissible check. A criterion for the selection shall be the date starting on which the time period needed to adjust the measurements outside the permissible limits is shorter.

4. Where points (1), (2) and (3) of this Article apply, the Operator shall adjust accordingly the Final Dispatch to Users and the charges to which this leads. The relevant adjustment shall appear in the next invoice issued by the Operator to each User.

Article 11. Lack of Reliable Information

In case of failure to take reliable measurements or in case of occasional interruption of the operation of the Metering Equipment at an Entry or Exit Point, the Operator may following consultation with the Users, on the reasons why such Point is an Entry or Exit Point under their respective applicable Transmission Contracts calculate an estimate of the Natural Gas quantity which is delivered or received through such Metering Equipment. For the purpose of this calculation, particular use is made of reliable measurements taken by the Metering Equipment at the given Entry or Exit Point under similar conditions during the respective time periods in the past.

Article 12. Information Record Keeping

1. The Operator shall keep record of all measurement information regarding Metering Equipment for at least two (2) years after their taking

2. The Operator shall also keep record of all testing and calibration information regarding Metering Equipment for at least five (5) years after their performance.

Article 13. User Access to the Metering Equipment

1. Each User or User authorized representative shall be entitled to access to the Metering Equipment at each Entry or Exit Point in the Transmission Contract, submitting a request in writing to the Operator at least 3 days prior to the desired visit date. In such request, the User must indicate the date on which it wishes to make such visit, the estimated duration of the visit, the number of visitors, and the reason for which it requests such visit.

2. The Operator may reject the User’s request if the Operator considers that there are reasons rendering the visit impossible on the date requested by the User. In that case, in concert with the User, the Operator shall appoint a new visit date.

3. The User's visit shall be made under the supervision and guidance of the Operator specialized personnel. The User must take all necessary measures to avoid causing damages to the equipment and comply with the instructions and advice of the Operator personnel.

4. The User shall be exclusively liable for its personnel and representatives participating in the visit. The Operator’s personnel may refuse entry to or request exit from the Metering Equipment space to all or part of the visitors where for any reason they consider that there is risk for the safety of the people or equipment in such space.

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Article 14. Measurement Management

1. Measured Magnitudes are collected by the Metering Equipment and managed by the Measurement Management System - MMS (where available). It is pointed out that in general the MMS is not available for Type B exit points (see Article 32). A MMS installed at a NGTS Entry or Exit Point typically performs the following functions (where these are available) :

it sums up the respective quantities (energy, volume, mass) for all metering currents;

it checks and transfers the suitable chemical composition quality analysis to the flow calculator;

it calculates the required quantities for the reports (under both operating and reference conditions) and generates reports on a daily (hourly analysis) and monthly (daily analysis) level;

it stores the magnitudes measured and calculated (qualitatively and quantitatively) in record at least until the signature of the respective monthly reports;

it ensures the integrity of the above records and records any changes to them;

it provides a safe access mechanism for the possibility of changes to the station measurement parameters;

it communicates with the Operator's Supervisory Control and Data Acquisition system transmitting measurement and state data or accepts commands as is provided for in the basic design of the Supervisory Control and Data Acquisition system.

The records generated by the system are used in the generation of reports as are or following conversion to the reference units required by them, as the case may be.

2. The reliable operation of the MMS is checked periodically or when requested by the User at the responsibility of the Operator and in the presence of the User or its representative. The items checked included but are not limited to the following:

correct recording and management of the magnitudes measured;

precision of the magnitudes calculated;

completeness and precision of the reports generated.

3. Each User is entitled to receive a copy of the measurement reports concerning each Point where such User receives or delivers Natural Gas. Copies are generated by specialized Operator personnel, who take all necessary measures to avoid causing damages to the metering equipment and the measurement record.

Article 15. Measurement Reports

The Measured Magnitudes obtained from the Metering Equipment at each Entry or Exit Point are used to prepare the Measurement Reports. Where a Measurement Management System is not available, such reports are prepared on the basis of indications or reports obtained by the Metering Equipment.

Metering Reports are prepared by the Operator for each Entry and Exit Point and are also signed by the users who use the specific Points. Based on the Measurement Reports, the Quantity and the quality characteristics of the Natural Gas delivered to an Entry Point or received at an Exit Point of the NGTS are established.

15.1 Entry Point Reports

By 13:00 hours each Day, the Operator shall prepare the following Reports for each NGTS Entry Point regarding the natural gas quantities that have been received on the previous Day:

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15.1.1 Daily NG Quantity and Measurement Characteristics Report at Entry Point (Form 1)

Such report shall include the following magnitudes:

i. the overall delivered NG volume (VΝ) in Nm3

ii. the overall delivered NG energy (E) in MJ

iii. the Gross Calorific Value (GCV) in MJ/Nm3

iv. Pressure (P) in bara

v. delivery Temperature (T) in οC

vi. Relative Density rd

vii. the Wobbe index in ΜJ/Nm3

viii. the overall hydrogen sulphide (H2S) content of the NG in mg/Nm3

ix. the overall sulphur (S) content of the NG in mg/Nm3

x. the Water Dew Point in οC under reference conditions

xi. the Carbohydrate Dew Point in οC under reference conditions

If magnitudes (iii) to (xi) are measured constantly, the Report shall indicate their weighted average. If such magnitudes are measured at regular intervals, the Report shall indicate the arithmetic average of at least three measurement readings during the Day. Especially with regard to the Aghia Triada Entry Point, magnitudes (νiii) to (xi) inclusive are not measured.

15.1.2 Daily NG Qualitative Composition Report at Entry Point (Form 2)

Such report includes the Natural Gas % mole in terms of carbohydrates (CxHy), carbon dioxide (CO2), nitrogen (N2) and oxygen (O2).

15.2 Exit Point Reports

For each Metering Station of NGTS Exit Point which is an Exit Point declared by the User in accordance with Annex Α2, the OPERATOR's personnel shall prepare the following reports at the latest by 14:00 hours on the sixth (6th) calendar day of each month:

15.2.1 Monthly NG Quantity and Measurement Characteristics Report at a Metering Station Exit Point (Form 3)

Such report indicates for each metering current of the Station and per day of the given Contractual Month the overall NG volume delivered (VΝ) in Nm3, the overall NG energy delivered (Ε) in MJ, the Pressure in bara and the delivery Temperature in οC. It also indicates the sum of the delivered volume of NG (VΝ) in Nm3 and the sum of the NG energy delivered (Ε) in MJ, for all metering currents of the given Metering Station.

15.2.2 Monthly NG Qualitative Composition Report at a Metering Station Exit Point (Form 4)

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Such report includes the Natural Gas % mole in terms of carbohydrates (CxHy), carbon dioxide (CO2), nitrogen (N2) and oxygen (O2). It shall also indicate the Gross Calorific Value (GCV) in MJ/Nm3, Relative Density rd and the Wobbe index in ΜJ/Nm3. For all Type B Exit Points (see Article 32) which do not have a gas chromatograph, the above information shall be obtained from a neighboring Entry or Exit Point with a gas chromatograph.

15.3 Natural Gas Latent Quantities Report (Form 5)

1. Natural Gas Latent Quantities shall be the Quantities that regard:

Own consumption of Natural Gas (station A/C, Boilers, Dehumidification Units)

Natural Gas Losses due to maintenance works, function tests or necessary discharges

Corrections to the Magnitudes Measured due to equipment calibration, wrong readings or other causes.

2. By the sixth (6th) calendar day each Month, the Operator shall prepare for each Entry and Exit Point of the NGTS a Natural Gas Latent Quantities Report indicating for each Day of the previous Month the volume (VN) in Nm3, the Energy (Ε) in MJ and the Gross Calorific Value (GCV) in MJ/Nm3 for the Natural Gas Latent Quantities.

Article 16. Natural Gas Quantities Certification

16.1 Report Signing

1. The Entry Point Reports shall be signed by the Operator and the Users for which the given Entry Point is a declared Entry Point at the latest by 14:00 hours on the day following the Contractual Day to which they refer.

2. Monthly Reports as well as Latent Quantities Reports at an Exit Point shall be signed each month by the Operator and the Users for which the given Exit Point is a declared Exit Point at the latest by 14:00 hours on the seventh (7th) day of each calendar month.

3. In case of disagreement on the part of any one of the Parties with regard to the contents of the Measurement Reports, such disagreement shall be entered as a note in the Report, the Report shall be signed by the Parties and shall be considered temporary until the final settlement of the dispute, in accordance with the provisions of Clause 16 of the Transmission Contract.

4. For any dispute that may arise between the Parties with regard to the measured NG quantities or its characteristic magnitudes, the User or the Operator who believes to be affected shall inform in writing the other Parties that have a lawful interest in the Point involved in the dispute. An objection lodged by any party on any of the above shall not hold such party or the other Parties free from their obligations arising from the respective Contracts entered into by and between them.

5. Where one of the Users or the Operator is unable or refuses to sign any Report invoking reasons of Force Majeure, the provisions of Article 10 of the Transmission Contract shall apply.

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6. Any revisions of the Quantity Certifications that have arisen following the implementation of the provisions under points (3) and (4) of this Article shall only affect the values of the magnitudes that have been calculated using the revised values of such Reports. In that case, a settlement for all revised magnitudes shall be performed at the end of each calendar Month and the relevant sum shall be paid in fully with the immediately following invoice.

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16.2 Expert

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1. In case of disputes that arise with regard to measurement issues, the Parties shall undertake to make all possible endeavors to amicably settle such disputes in accordance with the provisions of clause 16.3 of the Transmission Contract. Where the settlement procedure has not been completed within thirty (30) days from the dispatch of the invitation for amicable settlement, the Parties may agree to take the disputes on measurement issues to be settled to a mutually accepted Expert.

2. Next is given the procedure followed to appoint the Expert:

a. the party that wishes for an Expert to be appointed shall notify such intention to their counterparty, providing in that notice details of the issue which such first party suggests that it be resolved by the Expert;

b. the Parties shall meet in order to reach an agreement with regard to the issue that needs to be resolved, as well as to the person to be appointed Expert;

c. where the Parties have not reached an agreement on the person to be appointed Expert within twenty one (21) Days from the service of the initial notice, then the Parties shall immediately bring such issue to the NETHERLANDS METROLOGY INSTITUTE (N.M.I), which shall appoint the Expert; the contact information of this Institute is:

Nederlands MeetinstituutPostbus 3943300 AJ Dordrecht (NL)Hugo de Grootplein -1BG DordrechtTel:+31 78 332332Fax +31 78 332309

d. if an Expert is mutually agreed or appointed, the Parties shall immediately and jointly notify to the Expert the appointment of the latter and ask the Expert to confirm within seven (7) Days from offtake of the notice whether the Expert wishes and is able to accept their appointment and under which conditions, which must be in line with the conditions under point 4e below; where such notice is not jointly made within fourteen (14) Days, either one of the Parties may serve a notice on behalf of both Parties to the Expert, also notifying such notice to the other party;

e. if the Expert does not wish or is unable to accept the appointment or has failed to confirm acceptance of their appointment within twenty one (21) Days from the notice, then, unless the Parties agree to appoint another Expert, any one of the parties may refer the issue to the NETHERLANDS METROLOGY INSTITUTE (N.M.I), of which it shall be requested to make a new appointment and the procedure shall be repeated until an Expert is found that accepts their appointment;

f. each party shall cooperate with their counterparty in order to agree on the person to be appointed Expert and further, to negotiate and agree on the terms of and the implementation of the agreement on Expert appointment, which shall be signed by both parties;

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g. the Expert may not be a person who:

(i) does not possess the educational and experience qualifications to issue an opinion on the issue; and/ or

(ii) at the time of their appointment (or within three (3) months prior to such appointment), that same person or a blood or kinship relative of direct stirpes or lateral linearity, and up to the second degree inclusive, is Director, executive, or employee of any one of the Parties or of an Associated Company of any one of the Parties; and/ or

(iii) at the time of their appointment, the Expert or a blood or kinship relative of direct stirpes or lateral linearity, and up to the second degree inclusive has been hired directly or indirectly as consultant by either one of the Parties or any Associated Companies of the Parties.

3. The Expert's fees shall be agreed upon by the Parties and paid by the Party who results to be wrong. Where both Parties are proven wrong the Expert’s fees shall be paid by both of them on a 50-50 basis.

4. Further, the following are agreed:

a. all information, data, and documents notified or delivered by one party to the Expert as a result of or in relation to the appointment of the latter, shall be considered confidential, and the Expert must return them to the party having furnished them by the end of the procedure; the Expert may notify any of the above information, data or documents to the Expert’s employees or Associated Companies which have the same obligations as the Expert, and which in case of violation shall be jointly liable with the Expert vis-à-vis the affected Party;

b. next is given the procedure followed for referring an issue to the Expert:

(i) the Expert must within fourteen (14) days at the latest from their appointment summon the Parties to a meeting where the Expert shall lay all issues that need clarification, as well as the procedural rules to be applied, and which must be in line with the terms and conditions of this article;

(ii) the Parties shall be able to provide information and details and expose their arguments to the Expert;

(iii) the Parties shall be required to provide the details and information and submit their arguments as soon as possible and in any case within forty five (45) days from the appointment of the Expert; the Expert shall not consider details, information and arguments that have been submitted past the forty five (45) day deadline, unless such details, information and arguments have been furnished in response to specific requests of the Expert;

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(iv) each Party shall incur the expenses required to provide all the details, information and arguments given by such Party, as well all expenses that regard the witnesses and persons appointed by them;

(v) all communication between the Parties and the Expert must be in writing and copies must be served to the respective counterparty; no meetings between the Expert and any one of the Parties may be held if both Parties have not been invited on time at least two (2) days in advance to attend such meeting;

(vi) the Expert’s decision must be in writing, detailed and fully justified and must be issued within three (3) months from the appointment of the Expert, unless the Parties agree otherwise.

c. if the Expert fails to issue a decision within the time limits established above, then any one of the Parties may by their declaration establish a deadline not later than thirty (30) days, by which the Expert must issue their decision, or else the Expert shall cease to have any competency and be required to refund the fees; a decision of the Expert that may be issued past the foregoing thirty (30) day deadline shall be null and void;

d. the Expert shall not be considered arbitrator but shall issue the required decision as Expert and the provisions on arbitration shall not apply to the Expert, the Expert's decision or the procedure required for the issue of the decision;

e. the Expert’s decision shall be final and binding upon the Parties. The Parties shall not bound by the Expert's decision only where following Arbitration it is found that such decision had been a product of fraud or material fallacy with regard to the actual facts; otherwise the Expert's decision shall constitute unquestionable evidence with regard to the issues it pertains to.

5. Regardless of the foregoing procedures, the Parties must continue to always fulfill their contractual obligations irrespective of the nature of the dispute and although the dispute has been referred for settlement in accordance with this Article.

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MEASUREMENT RULES & STANDARDS

Article 17. Measurement Standards

The Measurement Standards listed in Tables ΙV and V of this Measurement Regulation establish among others:

1. the metering methodology used to measure the volume or mass of Natural Gas with specific composition, pressure, and temperature by a suitable meter;

2. the dimensions, the manufacturing and installation methodology, and the operating conditions for the Metering Equipment;

3. the methodology and the calculations required to establish the volume and the Gross Calorific Value of the measured Natural Gas quantity;

4. the range and precision of each measurement and the meter calibration methodology;

5. the methodology used for the required testing for each Metering Equipment element.

Article 18. Analysis Standards (Gas Quality)

The Analysis Standards listed in Tables ΙV and V hereof establish among others the Natural Gas sample analysis procedure in accordance with the Gas Chromatogram principle. More specifically they shall establish the Natural Gas sampling method, the metering methods, the ingredients of the sample to be analyzed, as well as its required characteristics, the measurement range for each ingredient, the precision of the measurement and checks on the measurement results, as well as analysis traceability.

Analysis at the chromatograph concerns nitrogen, carbon dioxide, saturated carbohydrates up to six carbon atoms. Further, certain sulphur compounds are established at another chromatograph. In addition, Natural Gas may also contain other elements such as oxygen, methanol, carbohydrates with a higher number of carbon atoms, water, etc. at such small quantities that do not affect the precision of the method.

Article 19. Sampling Standards

ISO 10715 provides instructions on the collection, keeping and management of representative constant flow Natural Gas samples. It also provides instructions on the sampling strategy, the position of the sampling probe, and the design of the sampling equipment.

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MEASUREMENTS - CALCULATIONS - CORRECTIONS

Article 20. Measurements & Calculations

20.1 Volumetric Flow Measurement

This is the continuous measurements of the gas or LNG that passes through a pipeline cross section for a given time period.

20.2 Speed MeasurementThis is the determination of the speed of the gas or LNG at a given point of the flow pipeline cross section. It is used to establish the flow profile. The Point where the average speed of flow is determined is used by volume meters.

20.3 Mass MeasurementSuch measurement is taken using the following methods:

(a) establishing the Coriolis Force

(b) establishing volumetric flow and density

(c) establishing volumetric flow, pressure and temperature

(b) by weighing (acontinuous method).

20.4 Gross Calorific Value CalculationThis is calculated by determining the quantitative analysis of the Gas sample using the Gas Chromatography analyzer chromatogram using the procedure detailed in Article 22.1 hereof.

When the chromatogram represents all sample components, the results are normalized, accepting that the fraction of the total surface area of each peak is the same with the percentage ratio of the component in the sample.

20.5 Energy CalculationThe energy of the passing gas (MJ) is calculated on the basis of the calculated Gross Calorific Value of the gas and its volume.

Article 21. Correction Methods

Using these methods it is possible to compensate systematic errors of meters connected to flow calculators. This is achieved by drawing on the meter calibration certificates under conditions similar to those of their operations. Such a method is typically the volumetric flow correction method with linear interference in relation to the percentage of the meter maximum volume flow.

Article 22. Calculation Methods

22.1 Gas chromatograph

The gas chromatograph determines the gas composition.

The gas components determined are:

Methane C1

Ethane C2

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Propane C3

Isobutane i-C4

Regular butane n-C4

Isopentane i-C5

Regular pentane n-C5

Hexane and heavier carbohydrates C6+

Nitrogen N2

Carbon dioxide CO2

During each analysis the gas chromatograph carries out the following calculations in accordance with ISO 6976 (Tables IV and V):

Gross Calorific Value at reference conditions

Relative density

Density under reference conditions

The supervising computer receives each gas analysis from the gas chromatographs and calculates the average values of the above gas parameters on an hourly and daily basis.

The following also apply:

i. the last analysis received is acceptable provided it meets the criteria established in the supervising computer and the chromatograph is in normal operating condition;

ii. the chromatograph periodically carries out calibration gas analysis, either automatically or manually. The response factors for each component between two successive calibration analyses are checked. The discrepancies between them must be within the levels established under ISO 6974 (Tables IV and V).

iii. the gas analysis to be used is established on the basis of priority procedures for each point. When so required, the priority procedure is agreed upon with the Users at regular intervals;

iv. the analysis average values are computed on at least a daily basis.

22.2 Flow calculators and Supervising Computers - PTZ Correctors

The volume of the gas consumed is calculated separately for each meter run by the respective flow calculator.Flow calculators are designed to calculate the flow of energy and gas volume, considering the signals from the respective meter run metering device, the temperature, pressure, differential pressure transmission instruments, and the overall chemical analysis (using the supervising computers). More specifically flow calculators:

calculate the gas volume (m ) and volume flow rate (m /h) at meter run pressure and temperature (with regard to turbine meters, ultrasonic flow meters, rotary positive displacement meters, and orifice meters);

calculate the gas volume (m ) and volume flow rate (m /h) following the application of the error correction equation for the respective meter (turbine, ultrasonic flow meters) to the meter run pressure and temperature;

calculate the gas volume (Νm ) and volume flow rate (Νm /h) under normal pressure and temperature conditions (reference conditions);

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calculate gas compressibility under ISO 12213 (Table V) for meter run temperature and pressure conditions and the composition detected by the chromatograph;

calculate the energy of the passing gas (MJ) and the energy flow rate (MJ/h) on the basis of the calculated Gross Calorific Value of the gas and its volume.

All data generated by flow calculators are real billing data which are stored and processed by the supervising computer.

At the Station there may be installed two identical supervising computers to ensure 100% reserve. Supervising computers supervise flow calculators and chromatograph computers. Each supervising computer processes the results and calculates hourly values.

All of the above results are stored in the respective folders in the flow calculator. Pressures, temperature, differential pressure, compressibility, as well as other real time data are constantly updated to allow for the calculations of flow averages carried out by the supervising computer.

The principal role of each flow or supervising computer is to collect gas flow data from the connectors at meter runs, meters or transmitters, and calculate the volumetric flow under reference conditions, as well as energy flow. Flows are completed with hourly, daily and overall sums.

It is pointed out that at certain type B Exit Points (cf. Article 32) instead of flow and supervising computers there is only a type PTZ corrector which calculates and stores the hourly, daily and monthly volume flow values (Nm3). The Operator calculates the energy by using the Gross Calorific Value from the available chromatograph data at a neighboring point.

22.3 Volume calculation method under reference conditions for turbine, ultrasonic flow and rotary positive displacement meter runs.

Using such meters, gas supply is measured at operating pressure and temperature. To have a common reference base, such measurements are reduced to reference conditions. Such calculation uses the ΡΤΖ method. In accordance with such method, the following formula is used to convert the volume measured to reference conditions:

Where

Ρ: gas pressure,

Τ: absolute gas temperature,

V: gas volume,

m: measurement state,

b: reference state

Compressibility factor Ζ depends on the composition of the gas and the pressure Ρ and temperature Τ conditions. For ΡΤΖ correctors a fixed gas composition is taken (fixed Zb), hence Zm is calculated for the existing Pm, Tm conditions. The remaining magnitudes are received by the corrector by direct metering (Vm, Pm, Tm). In this way corrected supply Vb is calculated.

In this case, the chemical composition, Gross Calorific Value and relative density data are received by the chromatograph that is installed at the nearest metering station.

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The corrected PTZ volume calculation method can apply either using a PTZ corrector, or by the flow calculator using pressure and temperature transmitters.

22.4 Volume calculation method under reference conditions for orifice meter runs.

This method is based on measuring the differential pressure that develops before and after the orifice meter on the fluid characteristics and under the conditions in which the meter is used. Orifice meter manufacturing, installation and use characteristics are established in accordance with ISO 5167 (Tables IV and V). Using data such as pressure P, temperature T, fluid density ρ, differential pressure ΔP the flow of the mass Qm that enters the time unit through the orifice is calculated. Next, using such value with gas density ρ volume flow Q under operating (real) conditions is calculated, whereas normal volume flow Qn or volume flow under reference conditions is calculated also using density under reference conditions ρn. The above densities are measured either directly using densimeters, or under ISO 6976 (Tables IV and V) using gas chemical composition (ρn calculation), pressure, temperature, and compressibility (ρ calculation).

22.5 Volume calculation method under reference conditions for mass meter runs.

In this case, first the mass flow is determined, and then using density under reference conditions, volume flow under reference conditions is calculated.

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METERING INSTRUMENTS

Article 23. General

Metering instruments play an important part in the operation of the systems incorporated in the natural gas transmission network. Variables such as gas pressure, temperature, and flow are highly important parameters in the processes that take place at all Points of the network in general.

Such variables are measured by special instruments which are installed at Metering and Regulation stations, as well as at other Points in the network. So, the entire system is managed using these measurements of variable parameters by special metering instruments, either locally or even telemetrically, gas quantities to users are reduced to the final pricing form, the smooth operation of the system is checked constantly, the quality of incoming gas is checked, and basically the entire operation is carried out with due supervision and checks in a valid and efficient manner.

Article 24. Metering Instrument Definitions and Types

The term instrument shall mean a sensitive electrical or mechanical or pneumatic or digital variable parameter measuring, transmitting, or checking device, which is installed in the NGTS and is connected to the measurement process devices and parts. The various types of metering instruments may be classified depending on the type of measurements they take. Therefore, depending on the type of measurements taken, such instruments fall mainly under three categories, these are:

24.1 Indicating Instruments

Indicating Instruments measure and record the instant value of a variable basically relating to the measurement process and it is not necessary to store or record it in analog or digital format. Such instruments include: analog or digital manometer (pressure gauge), thermometer (measurement gauge), etc.

24.2 Data Loggers

Data Loggers are the instruments used to permanently or partially record the variable parameters of a process, aiming at the systematic recording of operating data necessary for the Operator to proceed to study and further analysis. In essence, such instruments, if analog, record on a paper surface (calibrated depending on the use) changes to the operating parameter in time. Digital data loggers record measurement data, depending on the desirable settings, in a digital memory from which they can be retrieved using a computer and be analyzed using suitable software. In this way and by using data loggers, the Operator of a system is able to store the various operating data for their required processing and for future use. Such instruments are used in many transmission system operation applications (e.g. metering data for gas pricing at delivery Points).

24.3 Summing Instruments

Summing Instruments which are also called meters (analog-mechanical or digital) record the overall value of an operating variable for a given time period, during which the instrument or the metering device for a given parameter had been operating. Such summing instruments which are widely used in the natural gas system such are for instance: the instrument recording the overall volume of the natural gas that has passed through a turbine meter or

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other type of meter during a certain period at the reference system Metering and Regulation stations.

The various metering instruments fall under the following two categories depending on whether they serve or not billing purposes:

24.4 Supervising Instruments

Supervising instruments aim at recording the instant value of a parameter in order to ensure the best supervision of the NGTS without such value being used for User billing purposes. Such instruments are for instance analog manometers.

24.5 Custody Transfer Instruments

Custody Transfer Instruments are those NGTS instruments that are used for Custody Transfer purposes under international standards, procedures and methods as laid down in Tables IV and V. These are accompanied by calibration certificates and are checked and/ or recalibrated either by special metrologic laboratories at determined time intervals (Table Ι) or by the OPERATOR personnel in accordance with the calibration procedures (Article 35, Table ΙΙ). Such instruments make up either the NGTS Station supporting metering equipment such as pressure, differential pressure, temperature transmitters or main metering equipment such as the various meter types (Table IV). Also Custody Transfer Instruments include Gas chromatographs, and Dew Point Analyzers.

Article 25. Main Metering Instrument Groups

With regard to the various groups in which metering instruments can be included, these are established by the various variables involved in the specific measurement procedures. In general the main variables for the Natural Gas Transmission System are:

Temperature

Pressure

Gas Flow

Therefore, the most important instrument groups with regard to the above variables can be summarized as follows:

Thermometers (Analog or Digital/ Transmitters)

Manometers (Analog or Digital/ Transmitters)

Flow Meters (Turbine, Rotary Positive Displacement, etc. meters)

Article 26. Temperature - Thermometers

26.1 Temperature Measurement Principles

The magnitude or the quantitative value of temperature may not be determined directly. Therefore, the temperature value is determined indirectly and on the basis of certain matter characteristics, which change as a function of temperature increases or drops. Such characteristic properties are:

Length or Volume (based on thermic expansion)

Electric changes (changes to elecrtric resistance)

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Visual properties

The following are widely used in the Natural Gas Transmission System either in the laboratory or in the measurement processes:

26.2 Thermic Expansion Thermometers - Mercury Piliform or Glass Tube Thermometers

Temperature increases lead to changes in the volume of solids, fluids and gases, namely the above forms of matter expand as a function of temperature increase. This is basically the main property on which the operation of plain mercury or other fluid thermometers is based (fluids expand as the temperature increases).

26.3 RTD-Resistant Temperature Detectors

RTD-Resistant Temperature Detector operate with a measurable change in the resistance of the metal or thermistor as a function of temperature. The metal used is platinum, copper or nickel and the thermistor is a metal oxide.

RTD electrical resistance changes as a function of temperature. An electric circuit similar to that of a Wheatstone bridge is installed in control systems designed to be used with RTDs. A continuous current in the bridge generates an Exit voltage which changes as a function of temperature.

26.4 Temperature Transmitters

Temperature Transmitters are used to transmit temperature to remote points from the physical point where the measurement is taken. The transmission or connection point transmits the temperature of the medium to a remote point and may be the system control center or units and the data processing and control systems for the measurement process.

The main operation principle of a temperature transmitter is to convert the temperature value to an electric signal from 4 mA to 20 mA, and transmit this to the final receiver, which receives such electric signal and converts it to temperature reading. The transmitter is calibrated using the above scale.

Article 27. Pressure – Pressure Gauges

The transmission system uses various pressure gauges, mechanical or digital. With regard to mechanical pressure gauging, the main principle of operation is that the existence of the static pressure of a fluid or gas medium causes the mechanical change of an accessory or part of the metering instrument. This change is converted to a measurement on a calibrated pressure scale using a mechanical indicator. With regard to the digital recording of the measurement reading, this is done by gauges that convert the primary value through an electronic process to an indication on a screen. Such instruments can be designed with increased precision, always depending on the application for which they are intended.

27.1 Pressure Transmitters

The main operation principle of a pressure transmitter is to convert the measurable pressure value to an electric signal from 4 mA to 20 mA, and transmit this to the final receiver, which receives such electric signal and converts it to pressure reading. The transmitter is calibrated using the above scale. Such instruments can be recalibrated using special devices (HART Communicator) for increased precision in readings and transmission.The pressure transmitter used to measure and transmit the absolute gas pressure to the NGTS Metering and Regulation Station uses a piezoresistive silicon sensor, which provides an

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increased level of precision and operation for absolute pressure measurements. The digital technology employed ensures high precision for the reading range, as well as communication of the measurement point (field) with the central data control processing area.

The sensor comprises a “Wheatstone bridge” electric circuit which has been created using silicon resistances on a silicon layer. The process pressure is transmitted using the isolated and filled with fluid orifice to the sensor element, leading to a very small displacement of the silicon layer. The resulting microforce (small mechanical tension) that is applied to the layer changes the electrical resistance of the Wheatstone bridge depending on the pressure applied. In this way a mechanical tension changes to an analog magnitude electrical conversion and a 4 - 20 mA signaling is transmitted to provide the measurable magnitude of the change to the final recipients of the measurement with reliability and increased precision.

Article 28. Flow Meters

28.1 Turbine Meters

Turbine meters are inductive meters widely used in the natural gas metering system. Its principle of operation is the following:

The gas enters the turbine meter through a flow normalizer, which imposes a smooth gas flow, then passes through a ring channel and causes the turbine to move. The gas current compression that takes place inside the ring channel increases the speed of the gas so as to provide higher rotation torque to the turbine. The turbine comprises a wheel with flaps arranged on it at an angle between 30 and 45°. The gas current causes the turbine to revolve at a speed proportional to the speed of the gas. The overall gas volume that goes through the meter during the time unit (supply) is equal to the speed of the gas multiplied by the ring channel surface area, and each revolution of the turbine corresponds to a specific gas volume passing through the meter. Depending on the Qmin/Qmax ratio, such meters fall under three categories:

Short range, Qmin/Qmax = 1/5

Medium range, Qmin/Qmax = 1 / 1 0

Large range, Qmin/Qmax = 1 / 2 0

Start supply is Qmax/100.

Allowable measurement errors for turbine meters are:

For Qmin < Q < 0.2Qmax, 2%

For 0.2Qmax < Q < Qmax, 1%

More detailed reference is made to this meter in standards EN 12261 and ISO 9951 (Table V).

28.2 Rotary Meters

Rotary meters are volumetric meters used to measure gas mainly at commercial and industrial customers. They are also called rotary positive displacement meters or rotary piston gas meters. A rotary meter comprises two pistons that rotate in opposite direction inside a fixed measurement chamber.

The measurement chamber and the gas exit are placed the one across from the other. The pistons are made so as to allow constant water tightness without the pistons touching at any position. The combined movement of the pistons is attained through two gears placed on the piston shafts.

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During the full rotation of the pistons around their axis, a gas quantity equal to four times the volume included between the piston in horizontal position and the measurement chamber passes through the meter.

Depending on the Qmin/Qmax ratio, such meters fall under three categories:

Short range, Qmin/Qmax = 1/5

Medium range, Qmin/Qmax = 1 / 1 0

Large range, Qmin/Qmax = 1 / 2 0

The starting supply ranges between Qmax/800 and Qmax/300.

Allowable measurement errors for rotary meters are:

For Qmin < Q < 0.2Qmax, 2%

For 0.2Qmax < Q < Qmax, 1%

More detailed reference is made to this meter in standard EN 12480 (Table V).

28.3 Ultrasonic Flow Meters

Ultrasonic flow meters are metering devices which comprise ultrasonic transceivers placed inside the metering device conductors. The principle of their operation is based on ultrasonic pulses transmitted by a transmitter and received by a receiver at an angle φ (Doppler phenomenon).

Without flow, a pulse from transceiver Α to transceiver Β shall travel at the same speed compared to the speed of a pulse from B to A (the speed depends on the transmission medium).

If inside the conductor there is gas moving at a speed other than zero, then the pulse from A to B shall travel at a speed (greater or less depending on the direction of the gas) other than that from B to A.

The two pulse transmission times are measured electronically, determining in this way the gas movement speed. Using the gas movement speed the flow can be calculated under operating and reference conditions.

Usually, multiple path devices with reflectors are used.

The usual measurement errors are:

For Qmin < Q < 0.05Qmax,1 %

For 0.05Qmax < Q < Qmax, 0,05%

More detailed reference is made to this meter in standard ISO AGA 9 (Table V).

28.4 Orifice Meters

At restriction type - orifice meters the pressure drops when the flow conductor diameter changes and the fluid speed increases. By establishing the pressure drop, the volumetric flow is determined. The fluid flow rate is proportional to the square root of the pressure drop.

More detailed reference is made to this meter in standard ISO 5167 (Table V).

28.5 Coriolis Mass Flow Meters

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Coriolis meters operate based on the principle that inertia forces are generated whenever a molecule inside a rotating body moves in respect of such body towards or away from the rotation center.

Therefore, the (direct or indirect) measurement of the Coriolis Force that the flowing fluid applies on a rotating tube can provide a measurement of the mass flow rate.

More detailed reference is made to this meter in standard ISO 10790 (Table V).

Article 29. Gas Chromatographs

The main characteristics of a gas chromatograph is the sample introduction chamber, the chromatographic column and the detector. The carrier gas is included in metal bottles and provided to the device using one or more pressure regulators. The carrier gas transfers the sample ingredients inside the column where they are separated from one another and go through the detector, which sends a signal to a recorder. The column, the sample introduction system and the detector are found in fixed temperature heated chamber. More detailed reference to the carrier gas, the sample introduction, the chromatographic columns, the filling material, the detectors, the qualitative and quantitative analysis and the normalization of results is made in standard ISO 6974 (Table V).

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METERING PROCEDURES

Article 30. NGTS Metering Station Equipment

The NGTS metering station equipment comprises the main equipment for flow and energy volumetric measurement and the supporting equipment for measuring static pressure, differential pressure and temperature in the meter run.

The NGTS metering station equipment falls under three categories:

1. turbine meters, rotary positive displacement meters, ultrasonic flow meters and supporting equipment: pressure, temperature transmitters or built-in pressure and temperature sensors in PTZ correctors

2. orifice meters and supporting equipment: static pressure, differential pressure, temperature transmitters, and densimeters.

3. mass meters without supporting equipment.

In all three types of metering equipment Gross Calorific Value per gas volume unit and relevant density are calculated as a function of the gas composition which is obtained from a gas chromatograph.

NGTS metering station equipment is described in the Tables attached to Appendix 2 for each NGTS station, including the respective possible overall errors of individual supporting instruments and the overall energy uncertainty. More details about the precision of instruments and the equipment in general are given in Article 6 on Uncertainty Studies.

Article 31. Measurement Procedures

The actions, reports and the necessary management of measurements at each Entry or Exit point shall be the subject matter of Measurement Procedures.

More specifically:

The User may deliver NG to the Operator for transmission through the NGTS at the following Entry Points:

At the Border Metering Station (BMS) at Sidirokastro, Serres which is interconnected upstream with the System of Bulgaria.

At the Aghia Triada Metering Station which is interconnected with the NGTS LNG gasification facility.

At the Kipi Metering Station that is interconnected upstream to the Transmission System of Turkey (future)

Quality specifications and the delivery and offtake conditions for each Entry and Exit point are established in Annex E.

A description of the Metering Stations and the design and operation specifications are given in Appendix 2.

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Article 32. Exit Points

The NGTS Exit Points are classified as "Type A Exit Points" and "Type B Exit Points" as is shown in Table VI (Table VIΙ lists future stations). This classification refers exclusively to the time period during which the User may be informed about the measurements taken.

Until 13:00 hours each Day, the Operator shall collect the information on the Natural Gas Quantity delivered by the Operator and offtook by the users at the Metering Station Exit Point during the previous Day. Such information is indicative and aim at informing the Parties with regard to the Allocation.

Each business Day every user may be informed by fax or e-mail about the indicative NG quantity delivered to them by the Operator on the previous Contractual Day at the given Metering Station, provided such Station is part of a user nominated Exit Point.

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CALIBRATION

Article 33. Equipment Calibration

Table ΙΙΙ lists the Metering Equipment calibration equipment along with precision of each respective instrument. The precision of a standard instrument must be at least three times better than the respective precision of the metering instrument to be calibrated.

Depending on the measured magnitudes to be calibrated, the calibration equipment is classified as static pressure, differential pressure, temperature, etc. calibration equipment.

Below are given the principal standard instruments (working devices) for static pressure, differential pressure, and temperature that are used in general and more specifically to calibrate the Operator's metering station equipment.

33.1 Static Pressure - Deadweight tester

The main tester for pressure is the Deadweight tester.

The principle of operation of a device used to generate a calibrated reference pressure is: a piston with an accurately known base surface area is placed inside a cylinder. Next, known standard masses are placed on the piston. A pump supplies oil at sufficient pressure to lift the standard masses. The force applied by the oil pressure on the surface of the piston is balanced by the weight of the standard masses.

33.2 Differential Pressure - Double Piston Standard Mass Tester

Double piston standard mass testers are used to calibrate differential pressure transmitters at their static pressure operation. The device mainly applies a common static pressure on the low and high pressure extremes of the differential pressure transmitter. Next, the low pressure extreme is isolated, and the high pressure extreme is successively calibrated at the desirable differential pressure range.

33.3 Static Pressure - Gas Pressure Controller (GPC) Standard Pressure

The GPC is an automatic pneumatic pressure tester and calibrator.

The pressure is measured by a triple range quartz sensor with an precision of +/- 0.005% for each measurement range.

33.4 Standard High Precision (PHP 602) type Thermometer

The PHP 602 is a highly accurate standard temperature measuring device. It is connected to and operates through a computer. A suitable software processes the measurements, calibrates the temperature sensors and issues a relevant report.

Its main applications are:

• temperature measurements using RTD sensors;

• bath temperature stability check.

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33.5 Hart communicator

The communication setting and level of the (static, differential) pressure or temperature transmitter are attained using a communication device which is called HART Communicator (Highway Addressable Remote Transducer).

Such device is not a metering device and requires no calibration. It is an electronic communication device through which it is possible to notify and set the pressure and temperature transmitter operation elements. All Exit variables this device sows are elements of the transmitter to which the communicator has been connected.

The most important operational parameters of the communicator and the measurement in general that may be displayed and managed include:

1. Real Entry magnitude (process variable - pressure / temperature)

2. Real analog exit (4 - 20 mA)

3. Metering Instrument Low Range Value

4. Metering Instrument High Range Value

Article 34. Metering Equipment Calibration Frequency

The Metering Equipment undergoes Precision Testing at regular intervals.

Table ΙΙ indicates the Metering Equipment Calibration Procedures as compared to the individual equipment.

A Calibration Procedure includes both Metering Equipment Precision Testing and Regulation against the standard reference equipment (working device) used by the Operator, called Calibration Equipment and is indicated in Table ΙΙΙ.

Users shall be invited to and entitled to attend Metering Equipment calibration by the Operator. Calibration results are entered in relevant forms.

The frequency with which calibration is performed by the Operator’s personnel is established in the Operator’s ANNUAL CALIBRATION SCHEDULE which is notified to Users in a timely manner (each December of the previous year).

The provisions of Article 4 of this Measurement Regulation are implemented in installing each element of the metering equipment at a NGTS Entry or Exit point.

The frequency of metering equipment recalibration at special metrological laboratories in Greece or abroad is in accordance with Table Ι and the relevant Calibration Certificate is issued.

Article 35. Metering Equipment Calibration Procedures

These procedures concern the periodic calibration of and the checks on the NGTS Metering Equipment and individual instruments (70/19 bar) (Table ΙΙ)

The objective of the procedures is to attain a uniform calibration and checking method at all Entry/ Exit Points resulting in the safe and reliable operation of the NGTS Metering Equipment.

35.1 Calibration of Two Turbine Meter Runs and Flow calculator Checking

This procedure includes:

Pressure and Temperature transmitter calibration using the respective Working Standards (Table ΙΙΙ)

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Flow calculator checking using a pulse generator (Table ΙΙΙ), checking the programmed parameters and the correction coefficient calculation employing a standard software

35.2 In Line Turbine Meter Checking

This procedure includes:

turbine meter checking by connecting two meter runs in line for a given time period and given volume and pressure flow conditions

checking of programmed parameters that regard the calibration characteristics of turbine meters in flow calculators

35.3 Calibration of two Ultrasonic Flow Meter Runs

This procedure includes:

pressure and temperature transmitter calibration using the respective Working Standards (Table ΙΙΙ)

checking of the programmed parameters and the correction coefficient calculation at the flow calculators using a standard software

35.4 Orifice Meter Run Calibration

This procedure includes:

pressure, differential pressure and temperature transmitter calibration using the respective Working Standards (Table ΙΙΙ)

checking of the programmed parameters and the correction coefficient, volume and energy flow calculation at the flow calculator using a standard software (Table III)

Note: the above procedure may also include a densimeter check

35.5 Orifice Meter Checking

This procedure includes:

visual checking of the orifice meter in accordance with ISO 5167 (Table V) and checking its internal diameter using a Micrometer (Table ΙΙΙ)

checking the programmed calibration parameters of the orifice meter at the flow calculator

35.6 Gas Chromatograph Calibration

This procedure includes:

checking the response coefficients that result from successive analyses of the standard gas based on ISO 6974 (Table V)

checking the composition values that result from successive standard gas analyses (Table ΙΙΙ)

checking the natural gas Gross Calorific Value calculation from the chromatograph in accordance with ISO 6976 (Table V) the certified composition of the standard gas at the chromatograph

35.7 Dew Point Analyzer Checking

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This procedure concerns checking the dew point Analyzer by using a device based on the chilled mirror principle (Chandler Dew Point Tester-Table ΙΙΙ).

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TABLES

ΠΙΝΑΚΑΣ Ι. Έλεγχος Μετρητικού ΕξοπλισμούTABLE Ι. Metering Equipment Checking

No. METERING

INSTRUMENTS (METERS)

CHECK FREQUENCY CHECK CERTIFICATE

1 TURBINE 5 years or when considered necessary following a periodic check

Certified Laboratory or national metrological institute Certificate

2 ULTRASONIC FLOW 5 years or when considered necessary following a periodic check

Certified Laboratory or national metrological institute Certificate

3 ORIFICE When considered necessary after a check performed at least once a year

Check by a specialized laboratory or the manufacturer

4 MASS Every 2 years Check by a specialized laboratory or the manufacturer

5 ROTARY POSITIVE DISPLACEMENT

8 years or when considered necessary following a periodic check

Certified Laboratory or national metrological institute Certificate

ΠΙΝΑΚΑΣ ΙΙ.TABLE ΙΙ. Διαδικασίες Βαθμονόμησης του Εξοπλισμού ΜέτρησηςMetering equipment calibration procedures

No. PROCEDURES ΕΠΙΜΕΡΟΥΣ ΟΡΓΑΝΑ ΜΕΤΡΗΣΕΩΝ -

ΑΝΑΛΥΣΗΣ INDIVIDUAL METERING - ANALYSIS INSTRUMENTS

1 Calibration of Two Turbine Meter Runs and Flow calculator Checking

Temperature Transmitters, Pressure Transmitters, Flow Calculators

2 In Line Turbine Meter Checking Turbine Meters, Flow Calculators

3 Calibration of two Ultrasonic Flow Meter Runs Temperature Transmitters, Pressure Transmitters, Flow Calculators

4 Orifice Meter Run CalibrationTemperature Transmitters, Pressure Transmitters,

Differential Pressure Transmitters, Densimeters, Flow Calculators

5 Orifice Meter Checking Orifice Meters, Flow Calculators

6 Water Dew Point Analyzer Checking Water dew point analyzer

7 Carbohydrate Dew Point Analyzer Checking Carbohydrate dew point analyzer

8 Gas Chromatograph Calibration Gas chromatograph

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TABLE ΙΙI. Calibration Equipment Standards

No. Magnitudes to be Calibrated Working Devices (Standards) Precision

(Indicative) Use

1

STA

TIC

PR

ESSU

RE

DIF

FER

ENTI

AL

PRES

SUR

EDeadweight Ball Manometer ±0.015% Differential Pressure Generation

2 Double Piston Deadweight Manometer (nominal conversion coefficient 0.5 Mpa/Kg) ±0.015% Differential and Static Pressure Generation

3 Gas pressure controller ±0.005% Static Pressure Generation - Indication

4 Barometer ±0.10% Barometric Pressure Indication

5

TEM

PER

ATU

RE

High Precision Thermometer (digital) ±0.014%+ 0.014oC Temperature Indication (portable instrument)

6 Mercury Thermometer ±0.1 oC Temperature indication

7 Temperature Bath ±0.1 oC Temperature Generation using high precision Thermometer for Temperature Indication

8 - Hart Communicator - Digital Communication with Static Pressure, Differential Pressure, Temperature transmitters

9 VOLUME FLOW Pulse generator Pulse Generation for Flow Calculator Control

10 WATER DEW POINT Chandler ±2 oC Water dew point determination

11

GROSS CALORIFIC VALUE GAS

COMPOSITION

Standard gas ±0.1% Standard gas mixture for Gas Chromatograph Calibration

12 DIAMETER Micrometer <±2 μm Orifice Meter Diameter Measurement

Note: this table is not exhaustive, but serves the purpose of illustrating the working standards used by the Operator for calibration. It may be revised annually.

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TABLE IV. Custody Transfer Instruments - (Measurement) Precision Standards - Procedures, Methods

PRICING INSTRUMENTS PRECISION (Indicative)

(MEASUREMENT) PRECISION

STANDARDS

MEASURED MAGNITUDES(UNITS)

CALCULATED MAGNITUDES(UNITS) METHODS

Coriolis Meters  ±0.7% ISO 10790 MASS(Kg)

CORRECTED VOLUME(Nm3)

MEASUREMENT

Turbine Meters ±0.37% ISO 9951EN 12261

UNCORRECTED VOLUME(m3)

Ultrasonic flow meters ± 0.7% AGA 9ISO 9951

Orifice meters ±0.5% (outflow coefficient) ISO 5167 Rotary Positive

Displacement Meters with lobes

±0.5% EN 12480ANSI B109.3

Densimeters ±0.2% ISO 6976-AGA 8 DENSITY(Kg/m3)

Pressure Transmitters ±0.15% EA 10/17, EN 837-1, EN 837-2, EN 837-3

PRESSURE(bar)

Differential pressure transmitter ±0.15% EA 10/17, EN 837-1, EN

837-2, EN 837-4DIFFERENTIAL PRESSURE

(mbar)Temperature Transmitters ±0.14% EA 10/11 TEMPERATURE

(oC )

Gas chromatographs

±0.2% (Gross Calorific Value) ISO 6568

ISO 6974ISO 6976

GAS CONTENT IN CXHY,C02,N2

(%mole)

GROSS CALORIFIC VALUE(MJ/Nm3)

GAS QUALITATIVE & QUANTITATIVE ANALYSIS ANALYSIS

Oxygen Analyzers -Gas Chromatographs ±50% OXYGEN

(%mole)

Gas chromatographs ±0.2% (Gross Calorific Value) ISO 19739 RSH,H2S

(mg/m3)Water dew point

analyzers ±2 ASTM/D 1142 H2O DEW POINToC (at 38,2 bar)

Carbohydrate dew point analyzers ±1 ASTM/D 1142 H/C DEW POINT

oC (at line pres. [bar])-  - ISO 10715 -   - SAMPLING

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Note: the standards refer to versions that are in force and may be revised or supplemented by the International Organizations issuing them.

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ΠΙΝΑΚΑΣ V. Ισχύοντα Πρότυπα Κανονισμού Μετρήσεων ΕΣΜΦΑTABLE V. NGTS Measurement Regulation Applicable Standards

Gas

Vol

ume

- Mas

s - E

nerg

y M

easu

rem

ent

ISO 9951 : Measurement of Gas flow in closed conduits – Turbine meters

EN 12261 : Gas Meters-Turbine gas meters

EN 12480 : Gas Meters-Rotary displacements gas meters

ISO 5167 : Measurement of fluid flow by means of pressure differential devices inserted in circular - cross section conduits running full – Orifice plates

ISO 5168 : Measurement of fluid flow – Evaluation of uncertainties

ISO 6976 : Natural gas – Calculation of calorific values, density, relative density and Wobbe index from composition

ISO 10790 : Measurement of Gas flow in closed conduits – Guidelines to the selection, installation and use of Coriolis meters (mass flow, density, and volume flow measurements)

ISO 12213 : Natural gas – Calculation of Compression Factor

AGA 3 : Orifice Metering of Natural Gas

AGA 7 : Measurement of Gas by Turbine Meters

AGA 8 : Compressibility Factor of Natural Gas and Related Hydrocarbon Gases

AGA 9 : Measurement of Gas by Multipath Ultrasonic Meters

AGA 11 : Measurement of Gas by Coriolis Meter

ANSI B109.3

: Rotary -Type Gas Displacement meters

GUM    Guide Uncertainty of Measurement

EN 1776 : Gas supply – Natural gas measuring stations – Functional requirements

Gas

qua

lity/

ana

lysi

s

ISO 6974 : Determination of cοmposition with defined uncertainty by gas chromatography

ISO 14111 : Natural gas – Guidelines to traceability in analysis

ISO 19739 : Natural gas – Determination of sulfur compounds using gas chromatography

ISO 6326 : Natural gas – Determination of sulfur compounds

ISO 6142 : Gas analysis – Preparation of calibration gas mixtures – Gravimetric method

ISO 6143 : Gas analysis – Comparison methods for determining and checking the calibration gas mixtures’ composition

ISO 6327 : Gas analysis – Determination of the water dew point of natural gas – Cooled surface condensation hygrometers

Sam

plin

g ISO 10715 : Natural gas – Sampling guidelines

Note: the standards refer to versions that are in force and may be revised or supplemented by the International Organizations issuing them.

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TABLE VI NGTS Exit Points

EXIT POINT STATIONS TYPE *

KERATSINI M KERATSINI Α

LAVRIO M LAVRIO Α

KOMOTINI Μ/R KOMOTINI Α

VFL M VFL Α

THESSALONIKIΜ/R EASTERN THESSALONIKI Α

Μ/R NORTHERN THESSALONIKI Α

PLATI Μ/R PLATI Α

ELPE M/R EKO Α

SALFASALFA Ι Α

SALFA ΙΙ Β

ATTICA

M/R EASTERN ATHENS Α

M/R NORTHERN ATHENS Α

M/R WESTERN ATHENS Α

M/R THRIASIO Α

M/R ASPROPIRGOS Α

M/R MARKOPOULO - TM2 Α

IRONAS M IRONAS Β

ENERGIAKI THESSALONIKIS M/R ENERGIAKI THESSALONIKIS ** Β

EASTERN MACEDONIA - THRACE

M/R KOMOTINI Α

Μ/R KAVALA Α

M/R XANTHI Α

CENTRAL MACEDONIA M/R SERRES Α

THESSALY

Μ/R NORTHERN LARISSA ΑΜ/R SOUTHERN LARISSA Α

Μ/R LARISSA INDUSTRIAL AREA ΒΜ/R KOKKINA ΑΜ/R VOLOS Α

STEREA ELLADA - EVIAΜ/R INOFITA Α

Μ/R LAMIA Β*

TABLE VIΙ Future NGTS Stations

No. STATION1 Μ - ΜΟΤOR OIL2 M/R SERRES ***3 M/R DRAMA4 M/R KOSMIO5 M/R XANTHI ***6 M/R KILKIS7 M/R ENERGIAKI THESSALONIKIS 8 Μ/R KATERINI9 M/R LAMIA

10 M/R THIVA

* The separation of Stations into Type A/ B is referred to in Article 32

** Metering station to be constructed. For the time being measurements are taken at a metering station not owned by the Operator

*** These stations operate as temporary stations (Appendix 2) with future specifications regarding the construction of new stations

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FORMS

Form 1. Daily NG Quantity and Measurement Characteristics Report at a Metering Station Entry Point

Form 2. Daily NG Quality Composition Report at a Metering Station Entry Point

Form 3. Monthly NG Quantity and Measurement Characteristics Report at a Metering Station Exit Point

Form 4. Monthly NG Qualitative Composition Report at a Metering Station Exit Point

Form 5. Erroneous Quantities Protocol

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DAILY NG QUANTITY AND MEASUREMENT CHARACTERISTICS PROTOCOL AT ENTRY POINT

  Entry point: ……………………………………………………….  

  Written on: ……………………………………………………….  

  Reference Date: ……………………………………………………….  

    TOTAL QUANTITY  

  Volume VΝ =…………………………….. Nm3  

  Energy =…………………………….. ΜJ  

    MEASUREMENT CHARACTERISTICS AVERAGE VALUE  

  GCV =…………………………….. MJ/Nm3  

  PENTRY =…………………………….. Barg or Bara  

  ΤEXIT =…………………………….. oC  

  rd =……………………………..  -  

  Wobbe Index =…………………………….. MJ/Nm3  

  H2S =…………………………….. mg/Nm3  

  Total Sulfur =…………………………….. mg/Nm3  

  H2Ο Dew Point =…………………………….. oC (in P=……….........barg)  

  HC Dew Point =…………………………….. oC (in P=……….........barg)  

           

REMARKS    1. Water and carbohydrate dew points refer to a pressure ≤ 80 barg

2. The values are weighted averages (values per hour) with the exception of the H2O and HC dew points which are the average of at least three (3) measurements

3. Energy measurements in MJ refer to GCV and to a temperature of 0 oC

4. Quantity measurements in Nm3 refer to 0 oC and 1.01325 bara conditions

           

 THE OPERATOR

 THE USERS

 …………………

 …………………

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DAILY NG QUALITY COMPOSITION PROTOCOL AT ENTRY POINT

  Entry point: ……………………………………………………….  

  Written on: ……………………………………………………….  

  Reference Date: ……………………………………………………….  

    TOTAL QUANTITY  

  C1 =…………………………….. %mole  

  C2 =…………………………….. %mole  

  C3 =…………………………….. %mole  

  i-C4 =…………………………….. %mole  

  n-C4 =…………………………….. %mole  

  i-C5 =…………………………….. %mole  

  n-C5 =…………………………….. %mole  

  C6+ =…………………………….. %mole  

  CO2 =…………………………….. %mole  

  N2 =…………………………….. %mole  

  O2 =…………………………….. %mole             

 THE OPERATOR

 THE USERS

 …………………

 …………………

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MONTHLY NG QUANTITY AND MEASUREMENT CHARACTERISTICS PROTOCOL AT EXIT POINT

                                 DAILY QUANTITY REPORT             Gas month :    Per contract month             printout mode :                    Page : 1 of 2  DELIVERY POINT: ……………………………………………              Contract Day Meter Run …         Sum of Meters Runs      Vb-c (m³) Vn(Nm³) E (MJ) P (bara) T (°C)   Vb-c (m³) Vn(Nm³) E (MJ) E(Gcal)

01                    02                    03                    04                    05                    06                    07                    08                    09                    10                    11                    12                    13                    14                    15                    16                    17                    18                    19                    20                    21                    22                    23                    24                    25                    26                    27                    

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28                    29                    30                    31                    

Totals                    

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MONTHLY NG QUALITY COMPOSITION PROTOCOL AT EXIT POINT

DAILY QUALITY REPORT                     Gas month :  Per contract month                       printout mode :   DELIVERY POINT: ……………………………………………….            Page : 2 of 2

 Contract Day C1(mol%)

C2(mol%)

C3(mol%)

i-C4(mol%)

n-C4(mol%)

i-C5(mol%)

n-C5(mol%)

neo-C5(mol%)

C6+(mol%)

N2(mol%)

CO2(mol%)

O2(mol%)

hs dry (MJ/Nm³) rd Zn Wobbe

01                                02                                03                                04                                05                                06                                07                                08                                09                                10                                11                                12                                13                                14                                15                                16                                17                                18                                19                                20                                21                                22                                23                                24                                25                                26                                27                                28                                29                                30                                31                                

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Averages                                

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MONTHLY NG ERRONEOUS QUANTITIES PROTOCOL AT ENTRY OR EXIT POINT

Point:……………………………………………………….Written on: ……………………………………………………….

Reference Date: ……………………………………………………….        

Day Station Total

CommentsVΝ GCV E Nm3 MJ/Nm3 ΜWh

1        2        3        4        5        6        7        8        9        10        11        12        13        14        15        16        17        18        19        20        21        22        23        24        25        26        27        28        29        30        31        

Total                 

THE OPERATOR     THE USERS……………………………     ……………………………

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APPENDIX 2STATION DESCRIPTION - TECHNICAL SPECIFICATIONS

ENTRY POINTS

Next follows the general description of the design - operation of the Metering Stations at all Entry Points.

General description of the design - operation of the M Aghia Triada Metering Station

This station comprises two metering runs the characteristics of which are given in a table below.

During normal station operation only meter run No 1 (main meter run) operates, while meter run No. 2 (backup meter run) is in standby.

To ensure the smooth operation of the equipment and the uninterrupted supply of the NGTS, meter run No 2 is turned on in parallel with meter run No 1 where flow requirements exceed the upper flow limit of current meter No 1. In this case the flow is automatically divided between the two meter runs. Such operation takes place where normal operating conditions of the Aghia Triad Metering Station are violated.

Meter run No 2 is also manually turned on, independently of meter run No 1, during maintenance work on meter run No 1.

Quality parameters are constantly monitored using gas chromatographs in line with the system. Gas composition is then transferred to the Measurement Management System - MMS (supervising computers), which use it, along with the pressure and temperature readings from the pressure and temperature transmitters, to calculate current gas compressibility. At the same time, the above are also forwarded to the flow calculators, which use such information to convert the pulses they receive from the flow meters to energy, mass, and volume flow rates.

Under normal operating conditions (full functionality) the station operates without the presence of personnel, as it is monitored by the OPERATOR’s SCADA system. However, all necessary measures are adopted to ensure that the station can be operated through the station control panel by OPERATOR personnel where (for technical reasons) the supervision and teleoperation of the station is not possible from the control center or under emergency conditions or when the OPERATOR finds this solution as the most suitable one in terms of operation.

General description of the design - operation of the Sidirokastro Border Metering Station

The Border Metering Station in Sidirokastro, Serres near the border of Greece with Bulgaria measures and regulates the flow of imported natural gas. The Station equipment includes filters, meters, chromatographs and other analyzers, heat alternators and boilers, regulation valves, as well as control systems for the operation of such facilities. Flow is measured at four parallel meter runs with a diameter of 16΄΄ using an orifice meter.

The main design specifications are listed below in a table.

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General description of the design - operation of the Kipi Metering Station (to be issued - Future Metering Station)

Provision is made for three meter runs in conjunction with the turbine meter and the ultrasonic flow meter in line for each meter run and the use of primary and backup chromatographs, as well as Measurement Management System (MMS).

EXIT POINTS

Next follows the general description of the design - operation of the Metering (M) or Metering/ Regulation (M/R) Stations at all Exit Points.

General description of the design - operation of orifice meter stations with ultrasonic flow meter for startup (Lavrio M Station and Komotini M/R Station)

The installed station comprises one part with parallel filters-separators with a condensate collector, a part with parallel runs (three at M/R KOMOTINI and four at M-LAVRIO) each of them fully equipped with an orifice meter, a "startup” system with dual ultrasonic meters, a gas exit isolation valve and the necessary branching valve which allows or not gas from passing when the startup part is on or off respectively, as well as intermediate and external collectors.

At M/R Komotini following the metering device there is a regulation device in line which comprises two regulation lines with one heat alternator on each one. There is also a container with three boilers as well as two gas entry metering-regulation lines to supply the boilers.

The main design specifications are listed below in a table.

Natural gas quality parameters such as calorific value, composition and water and carbohydrate dew point are constantly recorded by two gas chromatographs, one oxygen analyzer, a water dew point analyzer and one carbohydrate dew point analyzer.

The constantly recorded natural gas composition and its quality parameters are forwarded to the supervising computers and used together with other digital data coming from temperature and pressure transmitters to calculate compressibility.

The foregoing gas composition is also forwarded to measure flow, and it is used together with other digital data coming from temperature, pressure, and differential pressure transmitters from the respective flow calculators (orifice meters or ultrasonic meter) to calculate flow and energy.

All station operations are monitored and checked by a central control station using a computer (main and backup) system and programmable logical controllers (main and backup), so that the presence of personnel at the station is not necessary under normal conditions. However, provision is made for all necessary equipment are adopted to ensure that the station can be operated through the station control panel or locally by OPERATOR personnel where (for technical reasons) the supervision and teleoperation of the station is not possible using the SCADA system or under emergency conditions or when the OPERATOR finds this solution as the most suitable one in terms of operation.

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General description of the design - operation of the Ultrasonic Meter Station (M-Ironas)

An installation of dual ultrasonic meters, the respective flow calculators and the Measurement Management System (MMS). Provision is made for the installation of a chromatograph and a third backup meter run (also with an ultrasonic meter - flow calculator), connection with the SCADA system. The chemical composition for calculating the GCV and the Energy is obtained by the OPERATOR using information obtained from a gas chromatograph at a neighboring entry or exit point.

General description of the design - operation of Stations with a turbine meter, flow calculator, MMS and chromatograph (e.g. M-Keratsini, M-VFL, City Exit Points)

The description of such stations is similar to that of the Aghia Triada Metering Station, noting that the City Exit points also have a pressure regulator on each meter run.

General description of the design - operation of Stations with a turbine meter, flow calculator, chromatograph and without MMS (e.g. M-EKO)

The description of such stations is similar to that of the Aghia Triada Metering Station, noting that there is no Measurement Management System (MMS) and that there may be a pressure regulator on each meter run.

General description of the design - operation of Stations with turbine meter and/ or rotary positive displacement meter, with PTZ corrector without MMS and chromatographs (e.g. Μ-Markopoulo, Μ-Α Larissa Industrial Area, Μ-Kokkina, temporary stations).

The description of the stations is similar to that for the Aghia Triada Metering Station noting that the PTZ corrector replaces the flow calculator and the pressure and temperature transmitters, that there is no MMS, and that the chemical composition for the purpose of calculating the GCV and the Energy is obtained by the OPERATOR using information from a gas chromatograph at a neighboring entry or exit point. For calculating compressibility, account is taken of the determined gas quality values entered into the PTZ corrector.

Note: Only the Technical Specifications for those stations that pertain to each contract shall be added to this Appendix.

TABLES 1-25 with the individual design and operation specifications, the metering equipment and the installation details for all NGTS Metering/ Regulation Stations are attached to this Appendix 2.

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ENTRY POINTSENTRY POINTS

TABLE 1AGHIA TRIADA U-3020

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 °C / +50 °CMINIMUM/ MAXIMUM ENTRY PRESSURE 38.4 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE 37.9 barg / 66.4 bargMINIMUM/ MAXIMUM ENTRY TEMPERATURE + 3°C / + 19°CMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE -OPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 259777 Nm3/hMETER RUN NOMINAL CAPACITY 259777 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 2SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%     INSTALLATION DETAILS   METER CAPACITY G4000METER DIAMETER 400mmMETER RUN DIAMETER 400mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 2SIDIROKASTRO U-2010

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.3 & B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 47.75 barg / 55 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +6 ºC / +40 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +6 ºC / +40 ºCOPERATING PRESSURE -OPERATING TEMPERATURE -STATION DESIGN CAPACITY 359550 Nm3/hTECHNICALLY MAXIMUM STATION CAPACITY 437000 Nm3/hMETER RUN NOMINAL CAPACITY 218500 Νm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Orifice metersNUMBER OF INSTALLED METER RUNS 4NUMBER OF INSTALLED CHROMATOGRAPHS 3

SUPPORTING EQUIPMENT TOTAL POSSIBLE ERRORP=±0.15%. ΔP=±0.15%.

T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.65%     INSTALLATION DETAILS   METER CAPACITY -METER DIAMETER 220 mmMETER RUN DIAMETER 400 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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EXIT POINTSEXIT POINTS

TABLE 1LAVRIO U-3430

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ASME VIII Div.1DESIGN PRESSURE 40 bargDESIGN TEMPERATURE -10 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 26.5 barg / 37.5 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE 25 barg / -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +3 ºC / +26 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +26 ºCOPERATING PRESSURE -OPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 240000 Nm3/hMETER RUN NOMINAL CAPACITY 80000 Nm3/hULTRASONIC METER RUN NOMINAL CAPACITY 19000 Νm3/h   METERING EQUIPMENT  

METER (EQUIPMENT) TYPE4 Orifice & 2 Ultrasonic Meters

NUMBER OF INSTALLED METER RUNS 4+2NUMBER OF INSTALLED CHROMATOGRAPHS 2

SUPPORTING EQUIPMENT TOTAL POSSIBLE ERRORP=±0.15%. ΔP=±0.15%.

T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.65%     INSTALLATION DETAILS   METER CAPACITY -METER DIAMETER 150 mmMETER RUN DIAMETER 250 mmFLOW ALIGNMENT DEVICE DESIGN ISO 5167 Z3433

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 2KOMOTINI U-3570

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ASME VIII Div.1DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 40 barg / 55 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE 28 barg / -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +6 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +26 ºCOPERATING PRESSURE -OPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 108000 Nm3/hMETER RUN NOMINAL CAPACITY 54000 Nm3/hULTRASONIC METER RUN NOMINAL CAPACITY 20000 Νm3/h   METERING EQUIPMENT  

METER (EQUIPMENT) TYPE3 Orifice meters & Ultrasonic

meters

NUMBER OF INSTALLED METER RUNS 3+2NUMBER OF INSTALLED CHROMATOGRAPHS 2

SUPPORTING EQUIPMENT TOTAL POSSIBLE ERRORP=±0.15%. ΔP=±0.15%.

T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.65%     INSTALLATION DETAILS   METER CAPACITY -METER DIAMETER 115 mmMETER RUN DIAMETER 200 mmFLOW ALIGNMENT DEVICE DESIGN ISO 5167 Z3573

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 3KERATSINI U-3090

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 40 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 18 barg / 18.2 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE 17.6 barg / -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +3 ºC/ -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC/ -OPERATING PRESSURE 17.6 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 102153 Nm3/hMETER RUN NOMINAL CAPACITY 102153 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 2SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%     INSTALLATION DETAILS   METER CAPACITY G4000METER DIAMETER 400 mmMETER RUN DIAMETER 400 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 4IRONAS U-6020

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -29 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 25.5 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE 25 barg / -MINIMUM/ MAXIMUM ENTRY TEMPERATURE -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 45 bargOPERATING TEMPERATURE +10ºCMAXIMUM STATION CAPACITY 40000 Nm3/hMETER RUN NOMINAL CAPACITY 40000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Ultrasonic metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) -     INSTALLATION DETAILS   METER CAPACITY 2500 m3/hMETER DIAMETER 200 mmMETER RUN DIAMETER 200 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 5XANTHI ΤΜ3-Β

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +25 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 20000 Nm3/hMETER RUN NOMINAL CAPACITY 20000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine meterNUMBER OF INSTALLED METER RUNS 1+(1)NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.3%. T=±0.3οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±1.15%      INSTALLATION DETAILS   METER CAPACITY G 1000METER DIAMETER 150 mmMETER RUN DIAMETER 150 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 6KAVALA ΤΜ4-Α

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +25 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 10000 Nm3/hMETER RUN NOMINAL CAPACITY 10000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine meterNUMBER OF INSTALLED METER RUNS 1+(1)NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.3%. T=±0.3οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±1.15%      INSTALLATION DETAILS   METER CAPACITY G 400METER DIAMETER 150 mmMETER RUN DIAMETER 150 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 7SERRES ΤΜ3-Α

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +25 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 20000 Nm3/hMETER RUN NOMINAL CAPACITY 20000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine meterNUMBER OF INSTALLED METER RUNS 1+(1)NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.3%. T=±0.3οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±1.15%      INSTALLATION DETAILS   METER CAPACITY G 1000METER DIAMETER 150 mmMETER RUN DIAMETER 150 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 8KOMOTINI ΤΜ3-C

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +25 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 20000 Nm3/hMETER RUN NOMINAL CAPACITY 20000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine meterNUMBER OF INSTALLED METER RUNS 1+(1)NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.3%. T=±0.3οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±1.15%      INSTALLATION DETAILS   METER CAPACITY G 1000METER DIAMETER 150 mmMETER RUN DIAMETER 150 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 9MARKOPOULO TM2

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 28800 Nm3/hMETER RUN NOMINAL CAPACITY 28800 Nm3/h   METERING EQUIPMENT  

METER (EQUIPMENT) TYPETurbine meter & Rotary meter

NUMBER OF INSTALLED METER RUNS 1+1NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.3%. T=±0.3οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±1.15%      INSTALLATION DETAILS   METER CAPACITY G 1000 . G 160 (Rotary)METER DIAMETER 150 mmMETER RUN DIAMETER 150 mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 10NORTHERN ATHENS U-2910

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 32.1 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE -3 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +7 ºCOPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 110219 Nm3/hMETER RUN NOMINAL CAPACITY 110219 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G4000METER DIAMETER 400mmMETER RUN DIAMETER 400mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 11THRIASIO U-2960

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 36.5 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE -3 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 50705 Nm3/hMETER RUN NOMINAL CAPACITY 50705 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G2500METER DIAMETER 250mmMETER RUN DIAMETER 250mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 12EASTERN ATHENS U-2940

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 40 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 27.6 barg / 37.7 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE -2 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +11 ºCOPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 110219 Nm3/hMETER RUN NOMINAL CAPACITY 110219 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G4000METER DIAMETER 400mmMETER RUN DIAMETER 400mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 13ASPROPIRGOS * U-2970

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 30 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE -3 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / -OPERATING PRESSURE 28.9 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 100150 Nm3/hMETER RUN NOMINAL CAPACITY 100150 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G2500METER DIAMETER 300mmMETER RUN DIAMETER 300mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

* there is a isolated metering station with nitrogen under pressure. Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 14WESTERN ATHENS U-2990

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 26.8 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE -4 ºC / MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 110213 Nm3/hMETER RUN NOMINAL CAPACITY 110213 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G4000METER DIAMETER 400mmMETER RUN DIAMETER 400mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 15INOFITA U-2880

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 36.3 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +7 ºCOPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 26508 Nm3/hMETER RUN NOMINAL CAPACITY 26508 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G1000METER DIAMETER 200mmMETER RUN DIAMETER 200mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 16VFL U-2170

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 33.2 barg / 55 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE 32.7 barg / -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +7 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE -OPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 24309 Nm3/hMETER RUN NOMINAL CAPACITY 24309 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G650METER DIAMETER 150mmMETER RUN DIAMETER 150mmFLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 17NORTHERN THESSALONIKI U-2240

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35.6 barg / 55 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +6 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 72527 Nm3/hMETER RUN NOMINAL CAPACITY 72527 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G2500METER DIAMETER 300mmMETER RUN DIAMETER 300mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 18EASTERN THESSALONIKI U-2220    

INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 34.2 barg / 55 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +6 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +7 ºCOPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 72527 Nm3/hMETER RUN NOMINAL CAPACITY 72527 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G2500METER DIAMETER 300mmMETER RUN DIAMETER 300mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 19PLATY IMATHIAS U-2410

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 43.8 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +10 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +7 ºCOPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 21488 Nm3/hMETER RUN NOMINAL CAPACITY 21488 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G1000METER DIAMETER 200mmMETER RUN DIAMETER 200mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 20ΕΚΟ U-2250

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 39 barg / 55 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +6 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +4 ºC / +18 ºCOPERATING PRESSURE 34.5 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 18027 Nm3/hMETER RUN NOMINAL CAPACITY 18027 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G400METER DIAMETER 150mmMETER RUN DIAMETER 150mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 21NORTHERN LARISSA U-2520

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 45.4 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +8 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 25910 Nm3/hMETER RUN NOMINAL CAPACITY 25910 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G1000METER DIAMETER 200mmMETER RUN DIAMETER 200mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 22SOUTHERN LARISSA U-2530

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 45.4 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +7 ºC / +24 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / +7 ºCOPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 25910 Nm3/hMETER RUN NOMINAL CAPACITY 25910 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G1000METER DIAMETER 200mmMETER RUN DIAMETER 200mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 23VOLOS U-2680

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -15 ºC / +50 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 45.3 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +6 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE +3 ºC / -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 51643 Nm3/hMETER RUN NOMINAL CAPACITY 51643 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS 1SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR P=±0.15%. T=±0.14οCENERGY UNCERTAINTY (FROM THE MANUFACTURER) ±0.47%      INSTALLATION DETAILS   METER CAPACITY G1600METER DIAMETER 250mmMETER RUN DIAMETER 250mm

FLOW ALIGNMENT DEVICE DESIGNISO 5167 Type C. bundle of 19

tubes

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 24LARISSA INDUSTRIAL AREA U-2515

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ΕΝ 1776DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +60 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +25 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 10000 Nm3/hMETER RUN NOMINAL CAPACITY 10000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR -ENERGY UNCERTAINTY (FROM THE MANUFACTURER) -     INSTALLATION DETAILS   METER CAPACITY G 400METER DIAMETER 150 mmMETER RUN DIAMETER -FLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

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TABLE 25ΚΟΚΚΙΝΑ U-2670

   INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ΕΝ 1776DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +60 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 35 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE -MINIMUM/ MAXIMUM ENTRY TEMPERATURE +5 ºC / +25 ºCMINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE 16.7 bargOPERATING TEMPERATURE -MAXIMUM STATION CAPACITY 10000 Nm3/hMETER RUN NOMINAL CAPACITY 10000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE Turbine metersNUMBER OF INSTALLED METER RUNS 2NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR -ENERGY UNCERTAINTY (FROM THE MANUFACTURER) -     INSTALLATION DETAILS   METER CAPACITY G 400METER DIAMETER 150 mmMETER RUN DIAMETER -FLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.

TABLE 26

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LAMIA TM5-R    

INDIVIDUAL DESIGN SPECIFICATIONS  DESIGN CODE ANSI B31.8DESIGN PRESSURE 70 bargDESIGN TEMPERATURE -24 ºC / +80 ºCMINIMUM/ MAXIMUM ENTRY PRESSURE 41 barg / 66.4 bargMINIMUM/ MAXIMUM OFFTAKE PRESSURE - / 37.7 bargMINIMUM/ MAXIMUM ENTRY TEMPERATURE +7 ºC / -MINIMUM/ MAXIMUM OFFTAKE TEMPERATURE -OPERATING PRESSURE -OPERATING TEMPERATURE -MAXIMUM STATION CAPACITY -MAXIMUM RUN CAPACITY 90000 Nm3/h   METERING EQUIPMENT  METER (EQUIPMENT) TYPE -NUMBER OF INSTALLED METER RUNS -NUMBER OF INSTALLED CHROMATOGRAPHS -SUPPORTING EQUIPMENT TOTAL POSSIBLE ERROR -ENERGY UNCERTAINTY (FROM THE MANUFACTURER) -     INSTALLATION DETAILS   METER CAPACITY -METER DIAMETER -METER RUN DIAMETER -FLOW ALIGNMENT DEVICE DESIGN -

Note: Where 2 is indicated it means there is a backup metering device of the same type installedWhere 1+1 is indicated it means there is a backup metering device of a different type installedWhere 1+(1) is indicated it means that there is provision for backup metering device.