- Specify HART communications as the preferred communications to transmitters used for fiscal metering.

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2 Distribution List The EGP Measurement Manual is a controlled document with the Master Copy maintained in the Enterprise Content Management System (ECMS). Electronic Distribution and notification to AAM Operations personal impacted by this Manual is via and includes a link to the document in the ECMS. The document is uncontrolled when printed. HARD COPY DISTRIBUTION Copy Number Location of Hard Copy 1 (MASTER COPY) Gas Transmission Technical Library 2 Control Room Manager, Gas Transmission 3 Gas Transmission Control 4 EGP Pipeline Marketing Manager 5 EGP ( Wollongong) Library ELECTRONIC DISTRIBUTION Via ECMS Via ECMS Via ECMS Via ECMS Via ECMS EGP Field Manager EGP Technicians Engineering Manager, Gas Transmission Manager Gas Transmission Asset Manager Metering Summary of Revisions: REV. 13 REV. 12 REV. 11 REV. 10 REV. 9 - Update the current Eastern Gas Pipeline Map - Update Smithfield and Hoskinstown with new details - Delete Bombala from Table 4 Frequency of Validations as it is not validated by Jemena - Add meter s capacity to Table 1 - Add Wilton Metering Station & Michelago Compressor Station - Add a fuel gas meter table - Review the Procedures - Formatting - Management of Validation activities if not performed on time. - The requirements to manage activities if not performed on time. - Specify HART communications as the preferred communications to transmitters used for fiscal metering. - Statements of compliance of the Jemena measurement equipment with the GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 2 of 63

3 requirements of National Greenhouse and Energy Reporting (Measurement) Determination 2008 included. - Reference to the Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement added with regard to the measurement uncertainties in the Jemena gas custody transfer scheme. - Requirements for calibration of the validation equipment added. - The appendixes, i.e. the general validation procedures and validation report example deleted, a re-drafted set of general validation procedures added. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 3 of 63

4 Table of Contents 1 SCOPE AND GENERAL Scope Application Terminology and Definitions Terminology Definitions Reference Documents GAS VOLUME MEASUREMENT General and Overview Meter Assembly Ultrasonic Meters Turbine Meters Coriolis Meter Transmitters, Sensors and RTD S Static Pressure Sensor Resistance Temperature Detectors & temperature transmitters Flow Computers Measurement Uncertainties FUEL GAS MEASUREMENT Fuel Gas Measurement with Coriolis Meters Fuel Gas Metering with Diaphragm Meters GAS QUALITY General Specifications Natural Gas Specification On Site Analysis Equipment Chromatographs Sulphur Analyser Moisture Analysers VALIDATION Validation overview Validation Overview Continual Periodic Validations Owners and Representatives Responsibilities Frequency of Validations Validation spreadsheet Val 51 Test equipment Val 52 Ultrasonic Diagnostic Check Val 53 Pressure Transmitter Val 54 Temperature Transmitter Val 55 Ultrasonic meter FC V s GOF Val 56 Gas Chromatograph Tolerance Check Val 57 Moisture Analyser Tolerance Check Val 58 Coriolis meter FC Check Val 60 Turbine meter FC V s GOF Val 61 Sulphur Gas Chromatograph Tolerance Val 62 Meter Comparison Val 63 Data transfer Check Val 64 Smithfield Rtu Data Comparison Calibration of the Validation Equipment METER CALIBRATION REFERENCE AND LOCAL CONDITIONS Reference Conditions Local Conditions Local Gravitational Acceleration GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 4 of 63

5 7.2.2 Local Atmospheric Pressure APPENDIX A PROCEDURE FOR VALIDATION OF ULTRASONIC METERS APPENDIX B PROCEDURE FOR VALIDATION OF TURBINE FLOW METERS APPENDIX C PROCEDURE FOR VALIDATION OF CORIOLIS FLOW METERS APPENDIX D GENERAL PROCEDURE FOR VALIDATION OF PRESSURE TRANSMITTERS APPENDIX E GENERAL PROCEDURE FOR VALIDATION OF TEMPERATURE TRANSMITTER APPENDIX F PROCEDURE FOR VALIDATION OF GAS CHROMATOGRAPHS APPENDIX G GENERAL PROCEDURE FOR VALIDATION OF MOISTURE ANALYSERS APPENDIX H PROCEDURE FOR VALIDATION OF SULPHUR GAS CHROMATOGRAPHS List of Tables Table 1: Eastern Gas Pipeline Metering Facilities... 9 Table 2: EGP Gas Quality Equipment Table 3: Outputs from On-Site Analysis Table 4: Frequency of Validations Table 5: Local Reference Conditions List of Figures Figure 1: Ultrasonic meter schematic Figure 2: Turbine Meter Schematic Figure 3: Coriolis Meter Schematic Figure 4: Daniel 500 Chromatograph Systems GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 5 of 63

6 1 SCOPE AND GENERAL 1.1 Scope This manual is to provide a technical reference for the operation and maintenance of the Jemena gas measurement and monitoring systems on the Eastern Gas Pipeline. A typical gas measurement system consists of the following processes: Equipment specifications Equipment calibration Data acquisition Data transmission Data, storage, manipulation and computation Data validation Billing procedures Discrepancy resolution and billing adjustments System auditing Gas Sales Contracts or Agreements This manual includes general details on technical aspects of the overall measurement system and equipment. Other aspects of the measurement process, such as billing procedures, system auditing, and billing adjustments are covered under separate procedures as part of the function of the GT Control. This manual is not intended to provide specific details of Gas Sales Contract terms and conditions. The Manual includes: General Information on validation of measurement data Specifications of measurement equipment Specifications of measurement tolerances and levels of uncertainty Details of calculations used for equipment calibration and data validation General Procedures for calibration of measurement equipment. Guidelines for Adjustment of measured flow quantity. 1.2 Application JEMENA is the measurement authority for the EGP. The scope of the manual applies to all JEMENA operated custody transfer facilities on the Eastern Gas Pipeline extending from the receipt facility at Longford to delivery facilities along the pipeline route and in Wollongong and Sydney. Map 1 and Table 1 provide an overview of the measurement facilities maintained on the Eastern Gas Pipeline at the time of issue of this Manual. Inspection and testing of both the fiscal and non-fiscal measurement equipment are addressed in this manual. For specific operational details refer to JEMENA standard operating procedures. The inspection and testing procedures for independently owned and operated measurement facilities on the EGP are not addressed in this manual. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 6 of 63

7 Gas Transmission South 13 Map 1: JEMENA Eastern Gas Pipeline GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 7 of 63

8 13 Location Status Meter Assembly Meter Runs Meter Diameter mm Pressure Range kpa Meter Flow Capacity Computer Pressure Temp. Transducer Pressure Transducer SCADA Moisture GC Sulphur Analyser Analyser Longford Suction Longford TGP Discharge Longford EGP Discharge Bairnsdale BPP Bairnsdale CG Ultrasonic Single 400 5,400-7,000 Ultrasonic Single ,000-14,890 Ultrasonic Single ,000-14,890 Coriolis Dual 50 10,000-14,000 Coriolis Single 25 10,000-14, , , ,000 30,000 4,000 Orbost Ultrasonic Dual 150 Bombala Note 1 Coriolis Single 25 N/A N/A Cooma Coriolis Single 25 10,500-11,000 Hoskinstown Ultrasonic Dual 200 3,800-14,900 Nowra Coriolis Single 25 8,000-14,800 Bomaderry Ultrasonic Single 80 8,000-14,900 Tallawarra Ultrasonic Dual 150 5,100-15,300 Albion Park Note 2 Ultrasonic Dual 80 3,800-14,895 11, ,500 11,800 51,970 80,000 38,503 Port Kembla Ultrasonic Dual ,500 Horsley Park Ultrasonic Dual 200 6, ,218 GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 8 of 63 publication may be reproduced, stored or transmitted in any form or by any means without the written permission of Jemena Ltd.

9 Smithfield Ultrasonic Dual 150 1,750-3,700 Wilton(APA) Ultrasonic Dual 200 6,000-12,000 Wilton(JGN) Ultrasonic Dual 200 6,000-12,000 Michelago Ultrasonic Single 400 5,200-14,895 Gas Transmission South 45, , , ,000 Table 1: Eastern Gas Pipeline Metering Facilities Note 1 Meter not owned and not validated by Jemena Note 2 Meter owned by Jemena Gas Networks. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 9 of 63 publication may be reproduced, stored or transmitted in any form or by any means without the written permission of Jemena Ltd.

10 1.3 Terminology and Definitions TERMINOLOGY Unless otherwise stated, all units and terminology used are in accordance with: Australian Standard AS ISO The International System of Units (The SI System) and Its Application and regulations thereunder Commonwealth Weights and Measures (National Standards) Amendment Act 1984 including Regulations Australian Gas Association publication Metric Units and Conversion Factors for use in the Australian Gas Industry To ensure the technical integrity of various standards and software sourced internationally, conversion factors commonly used and accepted in the Australian gas pipeline industry are used DEFINITIONS Bairnsdale BPP Bairnsdale CG Billing Period Bomaderry Calibration Gas GT Control Check gas Contract(s) Control Cooma Custody Transfer Delivered ECMS Energy Meter Station located at the Bairnsdale Power Station. Meter Station located at the Bairnsdale City Gate. The period from 0630 hours EST on the first day of each month to 0630 hours EST on the first day of the following calendar month. The Sales Offtake located in the Bomaderry MLV site. The gas used by a Gas Chromatograph to calibrate against known mole percentage values Gas Transmission Control The gas with a known concentration of H2S used to check that the flame in the Sulphur Gas Chromatograph flame is alight The various agreements for the transport of gas via the Eastern Gas Pipeline. Is a function of JEMENA in monitoring the Pipeline via the SCADA system and in executing the necessary actions and directives to ensure the effective receipt, transportation and delivery of gas to the Shippers. Meter Station located at the Cooma. Is the transfer of responsibility for the care and keeping of the gas. Gas having left the pipeline at the delivery point specified in the relevant contract as the point of transfer of custody of the gas from JEMENA to the relevant Shipper. Enterprise Content Management System The volume of gas in standard cubic metres multiplied by the Gross Heating Value (GHV). Standard units are Gigajoules (GJ). GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 10 of 63

11 Gas Transmission South Energy Accounting Gas Gas Used Gigajoule (GJ) Gross Heating Value (GHV) Imbalance Input Quantity ISO 6976 JEMENA Owned Gas JGN Joule HART Horsley Park Hoskinstown The determination of all quantities of gas added to or subtracted from and remaining in the JEMENA Pipeline system each billing period and the determination of the energy content of all such quantities of gas. Shall mean any naturally occurring mixture of one or more hydrocarbons in a gaseous state, and zero or more of the gases hydrogen sulphide, nitrogen, helium and carbon dioxide, and the residue gas resulting from the treating or processing of the natural gas. The amount of gas calculated by JEMENA to have been consumed by JEMENA in normal pipeline operations such as fuel for compressors, heaters, venting and instrument gas consumption. Equal to 10 9 Joules. Shall mean the energy produced by the complete combustion of one cubic metre of gas with air, at a temperature of 15 degrees Celsius and at an absolute pressure of kpa, with the gas free of all water vapour, and the products of combustion cooled to 15 degrees Celsius, the water vapour formed by combustion condensed to the liquid state, expressed in MJ per standard cubic meter (MJ/scm). Exists in relation to an agreement if there is a difference on any day between the quantities of gas received by the access provider at Receipt points for a facility user s account and the quantities of gas delivered to or on account of the facility user at the delivery points. The total of all gas received into the pipeline for a given billing period, as measured by the inlet meters. Natural Gas calculation of Calorific values, density, relative density, and Wobbe index from Composition. The quantity (in GJ) of gas in the pipeline equal to the sum of linepack and imbalance. Jemena Gas Network The energy expended or the work done when a force of one Newton moves the point of application a distance of one metre in the direction of that force. The HART Communications Protocol (Highway Addressable Remote Transducer Protocol) a digital industrial automation protocol. The facility, at the termination of the main section of the pipeline at Horsley Park. The facility providing metering and pressure reduction for the lateral supplying gas to Canberra. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 11 of 63

12 Kilopascal (kpa) Linepack Longford Compressor Station Suction/TGP/EGP Measurement Authority Measuring Equipment Megajoule (MJ) Month Nowra Orbost Off-specification Gas Output Quantity Petajoule (PJ) Pipeline Pipeline Controller Pipeline Inlet Pipeline Outlet Pipeline Owner Port Kembla Quantity Is one thousand Pascals and is by definition a measure of absolute pressure. It is sometimes convenient for instrument calibration to use the term kilopascal gauge. This means that the gauge reads zero at atmospheric pressure. The calculated quantity of gas contained in the pipeline at a given point in time (which is necessary for physical operation of the pipeline, excluding System use gas). The compressor station facility, constructed by the pipeline owner at the beginning of the main section of the pipeline at Longford. Is the Pipeline Owner. Includes but is not limited to the pipeline owner s meters, temperature and pressure transmitters, flow computers and gas chromatographs Joules. Period extending from the beginning of the first day in a calendar month to the beginning of the first day in the next calendar month. Refers to the Sales Offtake located in the Nowra MLV Site. Meter Station located at the Orbost. Gas other than Sales Specification Gas. The total amount of gas delivered by the pipeline in a given period as measured by the meters at pipeline outlet locations joules. The pipeline licensed under Victorian Pipeline Licence No. 232 and NSW Pipeline Licence No. 26 pursuant to the Petroleum Act. An employee of JEMENA working at the GT Control Room. The location(s) at which gas enters the pipeline, specified in the relevant contract as the point of transfer of custody of the gas from the relevant supplier to the shipper and simultaneously and instantaneously from the shipper to the pipeline owner. The location at which gas leaves the pipeline, specified in the relevant contract, as the point of transfer of custody of the gas from the pipeline owner to the shipper. JEMENA. The facility, at the termination of the Lateral section of the pipeline at Port Kembla. The quantity of gas measured in terms of its energy content. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 12 of 63

13 Gas Transmission South Received Reconciliation Sales Specification Gas SCADA Shipper Smithfield Specific Gravity Speed of Sound Standard Cubic Metre of Gas Standard Measurement Conditions Super compressibility Supplier System Use Gas Tallawarra Terajoule Validation or Verification Wilton(APA) Wilton(JGN) Wobbe Index Refers to gas having passed the inlet delivery point specified in the relevant contract as the point of custody transfer from the supplier to JEMENA. The process through which JEMENA conducts an energy balance at the end of each billing period, and allocates any System Use Gas in an agreed manner. Gas that meets all of the agreed requirements for content and properties. Supervisory Control and Data Acquisition and refers to the electronic means of receiving remote data and of sending remote control signals and data to pipeline facilities. An entity receiving transportation service on the pipeline pursuant to an effective Transportation Service Agreement (also known as the facility user or, in certain circumstances, access provider under the Pipeline Access Principles). The Meter station located in the boundary of the operating company of Marubeni Energy. The density of dry gas divided by the density of dry air, both at 15 C and at a pressure of kpa. The speed of sound for a particular gas composition. The unit of volume of gas free from water vapour which would occupy a volume of one (1) cubic metre at a temperature of 15 degrees Celsius and an absolute pressure of kilopascals. Defined as kpa and 15 C A factor expressing a deviation of a gas from perfect gas laws. The party contracted by a shipper to supply gas at any of the pipeline inlets for transport in the Eastern Gas Pipeline. The quantity of gas used in the operation of the pipeline, including, fuel gas and lost or unaccounted for gas. Meter Station located at the Tallawarra, Power Station and Injection point joules. The process of periodically checking and servicing the measurement equipment to ensure that it continues to function within agreed levels of accuracy. Wilton Meter Station measuring gas from EGP to APA Wilton Meter Station measuring gas from EGP to JGN The calorific value of the gas on a volumetric basis, at specified reference conditions, divided by the square root of the relative density of the gas at the same specified metering reference conditions. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 13 of 63

14 1.3.3 REFERENCE DOCUMENTS Measurement Standards: 1. American Gas Association Transmission Measurement Committee Report No. 7 Measurement of Gas by Turbine Meters American Gas Association Transmission Measurement Committee Report No 8 Compressibility Factors of Natural Gas and Other Related Hydrocarbon Gases Second Edition November 1992 Third printing November American Gas Association Transmission Measurement Committee Report No 9, Measurement of Gas by Multipath Ultrasonic Meters Second Edition April American Gas Association Transmission Measurement Committee Report No 11, Measurement of Gas by Coriolis Meter October AS Conversion Factors 6. ASTM D1072 Standard Test Method for Total Sulphur in Fuel Gases by Combustion and Barium Chloride Titration 7. ASTM D1142 Standard Test Method for Water Vapor Content of Gaseous Fuels by Measurement of Dew-Point Temperature 8. ASTM D1945 Standard Test Method for Analysis of Natural Gas by Gas Chromatography 9. ASTM D3588 Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels 10. ISO 6326 Natural Gas: Determination of sulphur compounds 11. ISO 6974 Determination of composition and associated uncertainty by gas chromatography 12. ISO 6975 Natural Gas: Extended analysis Gas chromatographic method GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 14 of 63

15 Gas Transmission South 13. ISO Natural Gas: Calculation of Calorific Values, Density, Relative Density and Wobbe index from composition. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 15 of 63

16 2 GAS VOLUME MEASUREMENT 2.1 General and Overview JEMENA is the Measurement Authority for the Eastern Gas Pipeline with responsibility for measurement and reconciliation of all gas received and delivered on the Eastern Gas Pipeline. JEMENA owns, operates and maintains gas quality measuring equipment at the Receipt Point(s) and at selected Delivery Points on the pipeline. Generally flow measurement facilities are maintained by JEMENA at each Delivery Point(s) and Receipt Point(s). Where Delivery or Receipt Point measurement equipment is owned or operated by a 3 rd party, they are maintained in accordance with this manual and JEMENA requirements. Data transfer from on-site RTUs to the SCADA system achieves remote monitoring of flow and gas quality. Land communications link the GT Control to on site measurement equipment at Receipt and key Delivery points. Measured flow is corrected for temperature and pressure to produce instantaneous volumetric and energy based flow rates at standard conditions in the on-site flow computer. The flow computer also calculates and maintains an accumulated record of volume and energy passing through the meter. In conjunction with line pack calculations, the accumulated quantities from each meter are used for the daily reconciliation and balancing of the pipeline. Shipper delivery points are equipped with Ultrasonic meters, Coriolis meters or Turbine meters. Diaphragm meters are used for heater fuel gas measurement at the meter and compressor stations. Coriolis meters are used as fuel gas meters at the Longford, Mila and Michelago compressor stations. The Data obtained from the flow computers of each meter is used to calculate the flow over the Billing Period. 2.2 Meter Assembly The meter assembly measures dynamic flow properties for use in the calculation of volumetric flow. Three styles of meter assembly are in service on the pipeline. JEMENA receipt points use ultrasonic flow meters. At the Delivery Points, a mixture of Ultrasonic, Coriolis and Turbine meters are employed. Coriolis meters are also used to measure the fuel usage at Longford and Mila Compressor Stations ULTRASONIC METERS The Ultrasonic meter measures the difference in time taken for sound waves to travel in the gas stream between up and downstream-paired transducers. Ultrasonic sound pulses are launched in each direction (as shown in Figure 1), their time of transit is measured, and the difference can be related to the speed of flow in the pipe. Ultrasonic meters have several sound wave paths through the gas in the pipe. Algorithms are used to derive the average flow velocity and determine if swirl or turbulence is present. The actual volumetric flow rate is calculated from the average velocity and the internal diameter of the meter. The Flow computer converts the actual volumetric flow rate to volumetric flow rate at Standard Conditions and Energy flow rate using inputs from pressure and temperature sensors and gas quality data. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 16 of 63

17 Gas Transmission South Figure 1: Ultrasonic meter schematic Where: D = Diameter of pipe L = Ultrasonic wave path distance A & B = Transducers ϕ = Angle between pipe axis and acoustic path v = Velocity of gas Ultrasonic meters are installed, operated and maintained as per the requirements of the American Gas Association (AGA) Report No. 9, second edition April 2007, and the manufactures installation, operating and maintenance manual. Periodic checks, called validations, are carried out to confirm the accuracy and integrity of the meter set. This includes checks of the Automatic Gain and Level Control, correct ultrasonic pulse rate and velocity of sound. This data indicates if any of the ultrasonic paths are fouled, the meter is subject to external noise or any of the ultrasonic transducers are deteriorating. Monitoring of the measured velocity of sound will show if there is any change in a critical dimension or the reference clock has drifted. Checks and calibration of temperature and pressure transmitters are also carried out during a validation. On-line diagnostics continuously monitor the performance of the meter. These diagnostic checks help to locate any metering discrepancies. Once identified, a discrepancy is investigated by JEMENA field staff. Metered data validations will be initiated to prove metering at any site as dictated by the field investigation. Where possible, delivery point meters will be operated in series with a nominated duty meter and stand-by meter. The following brands/types of ultrasonic meters are used on the EGP metering facilities: Daniel SeniorSonic Mark III, Sick Maihak FlowSick600 Instromet Q-Sonic The measurement uncertainties for these ultrasonic meters do not exceed 0.23% of their measurement range (Ref. Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement). Consequently, all ultrasonic meters, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section TURBINE METERS The turbine meter has a turbine rotor, which rotates as gas passes through it. Permanent magnets attached to the rotor tips turn with the rotor and produce magnetic currents in a coil causing a voltage pulse. Every time a magnet passes the coil a pulse is recorded and the total amount of gas that has gone through the meter is calculated. Straightening vanes are inserted in GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 17 of 63

18 the upstream section of the meter tube to aid in eliminating the turbulent flow patterns induced by the upstream piping allowing a concise meter reading as shown in Figure 2. Figure 2: Turbine Meter Schematic Turbine meters are installed, operated and maintained as per the current requirements of the AGA Report No. 7, second edition 1996 and the manufacturer s installation, operating, and maintenance manual. Temperature and pressure transmitters are located with each meter and are used to calculate the volumetric flow at Standard Measurement Conditions. At regular intervals agreed on by both JEMENA and the site customer, the in-service turbine meter is placed in series with another laboratory-calibrated meter. The throughput of each meter is measured and recorded. The results of the comparison must be within the required tolerance for continued use of the in-service turbine. The flow computer receives data from the meter, pressure and temperature transmitters and live gas quality data from a gas chromatograph, which enables calculation of gas volume and energy flow rates at standard conditions. Jemena EGP gas measurement facilities include one (1) site, equipped with the turbine meter, i.e. Smithfield Meter Station. The station is fitted with the Instromet type SM-RI-X meter. The meter is designed for the custody transfer applications in demanding industrial environment and it is manufactured and tested in accordance with the relevant International Standards, e.g. OIML R and ISO The typical uncertainty of the SM-R1-X turbine meter can be defined as ± 0.5% for 0.2*Qmax to Qmax (Ref. Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement). Consequently, the turbine meters, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section CORIOLIS METER The Coriolis meter uses an obstruction less U-shaped tube as a sensor. Inside the sensor housing, the sensor tube vibrates at its natural frequency. The sensor tube is driven by an electromagnetic drive coil located at the centre of the bend in the tube and vibrates similar to that of a tuning fork (Figure 3). GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 18 of 63

19 Gas Transmission South Figure 3: Coriolis Meter Schematic The fluid flowing into the sensor tube is forced to take on the vertical momentum of the vibrating tube. When the tube is moving upward during half of its vibration cycle the fluid flowing into the sensor resists being forced upward by pushing down on the tube. The fluid flowing out of the sensor has an upward momentum from the motion of the tube. As it travels around the tube bend, the fluid resists changes in its vertical motion by pushing up on the tube. The difference in forces causes the sensor tube to twist. When the tube is moving downward during the second half of its vibration cycle, it twists in the opposite direction. This twisting characteristic is called the Coriolis Effect. Electromagnetic velocity detectors located on each side of the flow tube measure the velocity of the vibrating tube. Mass flow is determined by measuring the time difference exhibited by the velocity detector signals. During zero flow conditions; no tube twist occurs, resulting in no time difference between the two velocity signals. With flow, a twist occurs with a resulting time difference between the two velocity signals. This time difference is directly proportional to mass flow. The flow computer receives data from the meter in terms of pulses/kg and live gas quality data from a gas chromatograph enables calculation of gas volume and energy flow rates at standard conditions. The Micromotion ELITE series H Coriolis sensor is typically used in the Coriolis measurement applications on EGP. The series R is also used but only for small fuel gas metering installations for power generator sets. The sensor is typically interconnected to the RF9739 or Series 2000 Coriolis transmitter. The uncertainty of the mass flow measurement for the above combination of the equipment is declared by the manufacturer as 0.5 % of rate, although the equipment calibration certificates indicate significantly better performance in the range of %. Following the manufacture s statement the uncertainty for the Coriolis gas custody transfer measurement is assumed to be 0.5% (Ref. Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement). Consequently, the Coriolis meters, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section Transmitters, Sensors and RTD S Transmitters, Sensors and Resistance Temperature Detectors (RTD) are mounted with each meter assembly depending on site requirements. They are used in the calculation of the correction factor that converts the actual metered flow to a net volume at standard measurement conditions. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 19 of 63

20 2.3.1 STATIC PRESSURE SENSOR The static pressure transmitter is comprised of a simple diaphragm of which one side is exposed to pressure. The amount of pressure placed on this diaphragm provides a corresponding distortion, which can be measured to give a static pressure reading. The static pressure sensing lines are leak tested and the transmitter is calibrated across its range. The flow computer display pressures are then compared to known test values. Accuracy of the Static pressure sensor and flow computer inputs is checked periodically as part of routine validations. The transmitter is calibrated across its range using a Dead Weight Tester (DWT) or an electronic pressure calibrator. A known pressure is applied to the transmitter. The pressure reading (kpa) from the flow computer display is compared to a known value. The DWT and electronic pressure calibrator is regularly bench calibrated at a NATA certified facility. Allowance is made for local gravity, barometric pressure head of oil and temperature for the DWT. For both the Ultrasonic and Turbine meters, pressure sensors are mounted on each meter assembly. The static pressure is used in the calculation, which converts the actual metered volumetric flow to a volume flow at standard conditions. A pressure sensor is also mounted on the Coriolis meters for pressure compensation of the sensor tube. For the Coriolis meters of the size of CMF100 and smaller, which are used on EGP, the pressure compensation does not affect the accuracy of meter readings thus the calibration checks on these pressure instrumentation may be carried out as non-fiscal. The following two brands of pressure transmitters are commonly used on EGP: Honeywell ST 3000 Smart Transmitter - the declared manufacturer s total uncertainty for the transmitter amounts to URL. Rosemount 3051 series Smart Pressure Transmitters the declared base uncertainty of the transmitter measurement is 0.04 URL. Both transmitters have the ability to transfer their sensor reading digitally. However the ST 3000 digital signal is proprietary with limited RTU compatibility. In contrast the open HART protocol found in Rosemount series transmitters has a larger support base. HART communications of pressure transmitter increase metering accuracy by reducing uncertainties introduced by the isolating barriers and RTU A/D modules. For this reason HART communications is the preferred communications protocol for fiscal pressure transmitters. For the purposes of the transmitter validation tolerance calculations the uncertainty of the pressure transmitter measurement is assumed to be 0.1 URL to allow for stability deterioration over time and to set reasonable validation targets (Ref. Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement). Consequently, all pressure transmitters, used on the Eastern Gas Pipeline Metering sites are compliant with the transmitter accuracy requirements, as defined in the National Greenhouse and Energy Reporting (Measurement) Determination 2008, refer Chapter 2, Part 2.3 Division Section 2.32, and Chapter 1, Part 1.1A, Division 1.1A.2, Section 1.10F RESISTANCE TEMPERATURE DETECTORS & TEMPERATURE TRANSMITTERS The operating principle of the Resistance Temperature Detector (RTD) is relatively simple. A platinum wire is fixed within a probe positioned mid-stream in the pipe. The resistivity of a conductor is proportional to its temperature. Hence, variation in gas temperature can be inferred from the variation in the measured resistance across the platinum wire. A Temperature GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 20 of 63

21 Gas Transmission South transmitter monitors the resistance across the platinum wire and converts it to a digital signal for use in flow calculations. Accuracy of the RTD and flow computer inputs is checked periodically as part of routine validations. The RTD temperature probes are calibrated using a water bath and a multi meter. The measured resistivity is compared to that of a NATA certified temperature probe. The temperature transmitters are calibrated using a certified resistance device. A known resistance is placed on the input to the transmitter and the expected temperature is compared to that indicated on the flow computer. The following types of the temperature transmitters are commonly used on EGP: Honeywell STT350 Smart Temperature Transmitter - the declared manufacturer s total uncertainty is 0.01 ºC, for the transmitter operating in the DE digital mode and in the range of ºC with Pt100 sensor. For the transmitter operating in analog 4-20 ma mode the uncertainties are in the range of 0.025%, i.e ºC. Rosemount 3144 series Smart Temperature Transmitters the declared base accuracy of the transmitters varies, depending on the variation of the Transmitter/Sensor arrangement, type of the sensor and the signal transmission techniques used. The declared manufacturer s total uncertainty is 0.1 ºC, for the transmitter operating as 4-20 ma in the range of ºC with Pt100 sensor. The manufacturer s declared ambient temperature effect for the transmitter operating with Pt100 in the ºC is ºC Both transmitters have the ability to transfer their sensor reading digitally. However the STT350 digital signal is proprietary with limited RTU compatibility. In contrast the open HART protocol found in Rosemount series transmitters has a larger support base. HART communications of temperature transmitter increase metering accuracy by reducing uncertainties introduced by the isolating barriers and RTU A/D modules. For this reason HART communications is the preferred communications protocol for fiscal temperature transmitters. For the purposes of this manual the uncertainty of 0.1%, i.e. 0.1 ºC have been assumed for all temperature transmitters, installed at the pipeline metering facilities (Ref. Jemena document GTS- 599-JJ-004 Uncertainty Calculations for Gas Measurement). Consequently, all temperature transmitters, used on the Eastern Gas Pipeline Metering sites are compliant with the transmitter and accuracy requirements, as defined in the National Greenhouse and Energy Reporting (Measurement) Determination 2008,, refer Chapter 2, Part 2.3 Division Section 2.32, and Chapter 1, Part 1.1A, Division 1.1A.2, Section 1.10F. 2.4 Flow Computers The flow computer performs three main functions: Computation of volume, mass, energy flow-rate and supercompressibility Calculation of flow Accumulation registers. Data transfer Each ultrasonic and turbine meter is connected to a local electronic flow computer, which receives and records the instantaneous values for all primary measurement inputs, i.e. volume flow signals from the meter as well as pressure and temperature information from the transmitters. From these inputs and along with the gas analysis, the flow computer continuously calculates the following: Instantaneous uncorrected volumetric flow GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 21 of 63

22 Instantaneous corrected volumetric flow Instantaneous energy flow Cumulative uncorrected volumetric flow Cumulative corrected volumetric flow Cumulative energy flow Super compressibility factor. Each Coriolis meter is connected to a local electronic flow computer, which receives a mass flow signal from the meter. Volume at standard conditions and energy flow rates through the meter are calculated from this signal and the specific gravity of the gas provided by a gas chromatograph. From these inputs and along with the gas analysis, the flow computer continuously calculates the following: Instantaneous mass flow Instantaneous corrected volumetric flow Instantaneous energy flow Cumulative mass volumetric flow Cumulative corrected volumetric flow Cumulative energy flow Super compressibility factor. Consequently, the flow computers, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section All calculations done by the computer are in accordance with recognised industry standards. Gas quality data electronically downloaded to each flow computer includes: Gross Heating Value Relative Density Nitrogen Content Carbon Dioxide Content Hydrocarbon Components Meter specific data Inputs manually programmed into the flow computers are: Site specific Atmospheric Pressure Contract Base Pressure Contract Base Temperature SCADA outputs from the computer are: Pressure Temperature Flow Rate Energy Rate GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 22 of 63

23 Accumulated Flow Accumulated Energy Specific Gravity Heating Value Gas componentry data Yesterday s energy Yesterday s volume Contract volume accumulator Contract energy accumulator Gas Transmission South Flow calculations are carried out as per the AGA standard appropriate to the metering apparatus and calculation of super compressibility for the purpose of flow correction as per the requirements of the AGA Report No. 8, second edition All functions of the flow computer are checked using electronic test instrumentation. Performing a flow calculation using measured properties substituted into custom software, and comparing the result with that from the flow computer assesses calculation accuracy. Details on Flow computer validation spread sheets can be found in Section Measurement Uncertainties The uncertainties in the Jemena custody transfer measurement system have been estimated and the results of the calculations are presented in the GTS-599-RP-004 Calculation of Measurement Uncertainties. The Wholesale Market Metering Uncertainty Limits and Calibration Requirements Procedures document, as produced in accordance with the requirements of the National Gas Rules 2008 (Version 18) by AEMO (Australian Energy Market Operator), was adopted for the assessment and benchmarking of the performance of the Jemena measurement facilities. On the basis of the calculations, all Jemena custody transfer facilities on Eastern Gas Pipelines can be declared as compliant with the AEMO uncertainty requirements for the volume and energy flow categories. 3 FUEL GAS MEASUREMENT Fuel gas is used on the EGP facilities to power the following equipment: Compressor Units Emergency Power Generators (GEA) Water Bath Heaters Hot Water Heaters The consumption of fuel gas at all facilities is measured and recorded. The Coriolis type meters are typically used for the compressor unit and GEAs and the diaphragm meters for the water bath and hot water gas heaters. As estimated, in excess of 80% of the fuel gas is consumed by the compressor units and the remaining less than 20% is shared between the GEAs and gas heaters. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 23 of 63

24 Location Meter Type Reading Use Longford Coriolis Flow Computer T610 Compressor Units Diaphragm Manual read Water Bath Heater Bairnsdale Diaphragm Manual read Water Bath Heater Diaphragm Manual read Water Bath Heater Orbost N/A N/A N/A Cooma N/A N/A N/A Hoskingtown Turbine Manual read Water Bath Heater Nowra N/A N/A N/A Bomaderry N/A N/A N/A Tallawara N/A N/A N/A Wilton Coriolis SCADA and Manual read Water Bath Heater Michelago CS Coriolis SCADA and Manual read To Gas Turbine and GEA Port Kembla Turbine SCADA and Manual read Water Bath Heater Smithfield N/A N/A N/A Horsley Park Diaphragm SCADA and Manual read Water Bath Heater 3.1 Fuel Gas Measurement with Coriolis Meters The Coriolis mass flow meter operating principle involves inducing a vibration of the flow tube through which the fluid passes. The vibration, though it is not completely circular, provides the rotating reference frame which gives rise to the Coriolis Effect. While specific methods vary according to the design of the flow meter, sensors monitor and analyse changes in frequency, phase shift, and amplitude of the vibrating flow tubes. The changes observed represent the mass flow rate and density of the fluid. Measurement accuracy of the Coriolis meter is a function of fluid mass flow rate independent of operating temperature, pressure, or composition. However, pressure drop through the sensor is dependent upon operating temperature, pressure, and fluid composition. All Jemena fuel gas Coriolis meter measurement applications are selected, installed and operated in accordance with the American Gas Association Report No 11 Measurement of natural gas by Coriolis meters. The field maintenance is performed on the meters, as per the Report. The maintenance consists of monitoring and evaluating metering conditions, as well as the diagnostic information as produced by the transmitter and the ancillary devices, to identify possible changes in the system performance and the causes of the changes. The evaluation is used to determine the need for the meter performance tests. The tests include the following: Zero check Sensor diagnostic check Transmitter diagnostic check The consumption of the fuel gas, as measured by the Coriolis meters, is processed and corrected in the flow computers. The resulting information on the volumetric and energy consumption is monitored and recorded on continuous basis via the Jemena SCADA facilities. The Coriolis type primary sensors, typically Rosemount Elite, R-style or F-style, are used on Jemena facilities for measurement of fuel gas consumption on the compressor units and GEAs. The sensors are typically paired with the RF9739 or Series 2000 Coriolis transmitters. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 24 of 63

25 Gas Transmission South The uncertainty of the fuel gas consumption measurement for the above combination of the equipment is declared by the manufacturer as 0.5 % of rate, although the equipment calibration certificates indicate significantly better performance in the range of %. Following the manufacture s statement the uncertainty for the Coriolis gas custody transfer measurement is assumed to be 0.5% (Ref. Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement). Consequently, the Coriolis meters, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section 2.35 Each Coriolis meter is connected to a local electronic flow computer, which receives a mass flow signal from the meter. Volume at standard conditions and energy flow rates through the meter are calculated from this signal and the specific gravity of the gas provided by a gas chromatograph. From these inputs and along with the gas analysis, the flow computer continuously calculates the following: Instantaneous corrected volumetric flow Cumulative corrected volumetric flow Supercompressibility factor All flow computers accumulate volume and energy totals. Consequently, the flow computers, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section Fuel Gas Metering with Diaphragm Meters Diaphragm meters are positive displacement type of the measuring device, which have fixedvolume measurement compartments formed by two-sided convoluted diaphragm. A small pressure drop across the meter causes it to cycle so these compartments alternatively fill with gas at the inlet. And then empty at the outlet. By counting the number of cycles, the meter provides a measure of gas volume. The AL series of diaphragm meters is used at Jemena for measurement of fuel gas consumption. The meters are housed in the aluminium alloy case, which is cast in one piece thus eliminating joints and gaskets and the resulting possibilities of internal leaks and malfunctions due to component aging process. The meter has been designed with aim to provide a long term accurate and maintenance free operation by eliminating or minimising friction of the moving parts and the use of self-lubricating joints. The diaphragm meters are commonly used in the gas distribution networks with millions of applications around the world. However, the application of the meters in the gas transmission facilities is, with regard to the nominal pressure and the measuring range of the meter, limited only to the fuel gas measurement. Consequently, the diaphragm meters, used at Jemena, can be classified as the distribution type meters. Calibration & Replacement of these types of meters must be in accordance with Jemena s Metering Strategies, which includes: a new meter is placed in service After any repairs, maintenance or recalibration performed on a meter then placed back into service The typical uncertainty of the AL1000 or equivalent diaphragm meter can be defined as ± 1.0% for Qmin to Qmax (Ref. Jemena document GTS-599-JJ-004 Uncertainty Calculations for Gas Measurement). GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 25 of 63

26 Consequently, the diaphragm meters, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section Each diaphragm meter is connected to a local electronic flow computer, which receives and records the instantaneous values for all primary measurement inputs, i.e. volume flow signals from the meter as well as pressure and temperature information from the transmitters. From these inputs and along with the gas analysis, the flow computer continuously calculates the following: Instantaneous corrected volumetric flow Cumulative corrected volumetric flow Instantaneous uncorrected volumetric flow Cumulative uncorrected volumetric flow Supercompressibility factor. Consequently, the flow computers for the diaphragm meters, used on EGP, comply with the National Greenhouse and Energy Reporting (Measurement) Determination 2008 Chapter 2, Part 2.3 Division Section GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 26 of 63

27 Gas Transmission South 4 GAS QUALITY 4.1 General Gas entering the pipeline must meet certain specifications before it is transmitted through the line. JEMENA monitor the gas quality to ensure it meets these specifications. The gas quality equipment currently installed on EGP is as per the following table: EGP Gas Quality Equipment Location Measurement Type Brand Model No Longford C6+ Gas Chromatograph Daniel Danalyser A Controller Longford C9 Gas Chromatograph Daniel Danalyser A Controller Longford H2S Analyser Daniel Danalyser A Controller Longford Moisture Analyser Spectra Sensors SS2000 Orbost C6+ Gas Chromatograph Daniel Danalyser A Controller Orbost C9 Gas Chromatograph Daniel Danalyser A Controller Orbost H2S Analyser Daniel Danalyser A Controller Orbost H2S Analyser Daniel Danalyser A Controller Orbost Moisture Analyser Ametek OLV (Primary) Orbost Moisture Analyser Ametek 5100 HD (under review) Port Kembla C6+ Gas Chromatograph Daniel Danalyser A Controller Port Kembla C6+ Gas Chromatograph Daniel Danalyser A Controller Port Kembla H2S Analyser Daniel Danalyser A Controller Port Kembla H2S Analyser Daniel Danalyser A Controller Smithfield C6+ Gas Chromatograph Daniel Danalyser A Controller Smithfield C6+ Gas Chromatograph Daniel Danalyser A Controller Wilton (APA) C9 Gas Chromatograph ABB NGC8209 Table 2: EGP Gas Quality Equipment 4.2 Specifications The JEMENA Standard Terms and Conditions for the Eastern Gas Pipeline state the acceptable gas quality limits that apply to gas to be transported. Those requirements are restated in Table 3 below. JEMENA is contractually obligated to flow, on behalf of its Shippers, only gas that meets the specification. It is the Shipper s responsibility to ensure that gas to be transported meets this specification at its Receipt Point(s). JEMENA will immediately notify the Shipper and Supplier when gas is not meeting specifications as identified by JEMENA gas quality measuring devices at the Receipt Point(s). Steps as outlined in Section 4 of the Standard Operating Procedure EGP Red Alarms Gas Quality Procedure (GTS-500-PR-PC-001) may be taken by JEMENA in the event of off-specification gas. However, neither this action, nor the knowledge of the presence of off-specification gas by JEMENA personnel relieve the Shipper from its contractual obligation for providing gas meeting specifications, or liability for any consequential damage incurred by Shippers directly or indirectly due to the acceptance of off-specification gas on behalf of a Shipper. GTS-599-TR-GM-001 EGP Measurement Manual Rev 13 _Revised May 2017 Page 27 of 63