m r design specs

Dominion Transmission, Inc. 445 W. Main St.

Clarksburg, WV 26301 Engineering Services Department

Specification for

Measurement & Regulation Stations

Specification No.: 52 Revision No.: 3.0 Approval Date: 3/25/2013 Last Reviewed Date:

Project Name: Rev. No. Date Revision

Approved By Dominion Other

Issued for Review Issue for Quotation Issued for Purchase

Rev. No. 3.0

Specification for Measurement & Regulation

Stations

Spec. No. 52

Rev. Date 3/25/2013

Filename: (In File Net) Last Revised: Page Number 52 electronic flow measurement spec. doc 3/25/2013 2 of 40

TABLE OF CONTENTS

1. Introduction .......................................................................................................................... 5

2. General ................................................................................................................................. 6

2.1. Codes&Standards........................................................................................................................6

2.2. RequiredDesignData...................................................................................................................7

2.3. MeterStationSizing......................................................................................................................7

2.4. DrawingApprovals........................................................................................................................7

3. Meter Station Site ................................................................................................................ 8

3.1. Locations.......................................................................................................................................8

3.2. Structures......................................................................................................................................8

3.3. Lighting........................................................................................................................................10

3.4. Foundations................................................................................................................................10

4. Major Station Piping .......................................................................................................... 10

4.1. MajorPiping................................................................................................................................10

4.2. Headers.......................................................................................................................................11

4.3. FlowControl&PressureRegulation...........................................................................................11

4.4. MeterRunPiping&TubingConfigurations................................................................................13

5. Overpressure Protection ................................................................................................... 14

5.1. General........................................................................................................................................14

5.2. ReliefValvesasOverpressureProtection...................................................................................14

5.3. PressureRegulatorsasOverpressureProtection.......................................................................14

6. Primary Measurement ....................................................................................................... 15

6.1. UltrasonicMeters.......................................................................................................................15

6.2. OrificeMeters.............................................................................................................................16

6.3. TurbineMeters...........................................................................................................................16

6.4. CoriolisMeters............................................................................................................................17

6.5. PositiveDisplacementMeters....................................................................................................18

7. Secondary Measurement Devices .................................................................................... 20

7.1. Transmitters................................................................................................................................20

8. Tertiary Measurement Device ........................................................................................... 22

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8.1. InstallationCriteria......................................................................................................................22

8.2. GasFlowComputer(GFC)Types.................................................................................................22

8.3. EFMGrounding...........................................................................................................................22

8.4. Isolation&IntrinsicallySafeWiring............................................................................................23

8.5. Interfacing...................................................................................................................................23

8.6. RemoteControl...........................................................................................................................24

8.7. ElectronicRunSwitching............................................................................................................24

9. Tubing ................................................................................................................................. 25

9.1. Size..............................................................................................................................................25

9.2. Installation..................................................................................................................................25

9.3. Material.......................................................................................................................................25

10. Gas Sampling ..................................................................................................................... 26

10.1. SamplerRequirements...............................................................................................................26

10.2. SampleProbe..............................................................................................................................26

11. Gas Chromatographs ........................................................................................................ 27

11.1. ChromatographLocationRequirements....................................................................................27

11.2. ChromatographInstallationRequirements................................................................................27

11.3. Tubing.........................................................................................................................................27

11.4. SampleProbe..............................................................................................................................28

12. Odorization ......................................................................................................................... 29

13. Gas Quality ......................................................................................................................... 29

14. Other Considerations ........................................................................................................ 30

14.1. FuelGas.......................................................................................................................................30

14.2. Dehydration................................................................................................................................30

14.3. Heating........................................................................................................................................30

14.4. FilterandSeparation...................................................................................................................30

15. Standard Wiring & Electrical Requirements ................................................................... 31

15.1. GeneralElectricRequirements...................................................................................................31

15.2. GeneralGroundingRequirements..............................................................................................32

15.3. ME&STypicalWiringTable.........................................................................................................33

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15.4. JunctionBoxes............................................................................................................................35

15.5. ME&STypicalTerminalStripLabelingTable...............................................................................36

16. Communication .................................................................................................................. 39

17. Integrity & Corrosion ......................................................................................................... 39

18. Standard Material Specification ....................................................................................... 40

19. Standard Drawings ............................................................................................................ 40

20. Waivers & Variances ......................................................................................................... 40

21. Appendices & Attachments........40

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1. Introduction

This document shall serve as the minimum specifications for the measurement and regulation design requirements for facilities that are operated and/or maintained by Dominion Transmission. The specifications shall apply to natural gas transmission pipeline companies and all other parties that interconnect with Dominion Transmission pipelines and related facilities.

It is required that all designs, drawings, and specifications be reviewed and approved by Dominion Transmission prior to the commencement of fabrication and construction activities. All requests for modification of the measurement facility design from this document must be submitted in writing for review and approval by Dominion Transmissions Measurement Engineering & Support engineers. Failure to obtain written approval for designs and fabrication drawings will result in project delays.

This document will not supersede applicable safety, code, and other applicable standards and recommendations. Given the rapid changes in technology and standards within the natural gas industry, all parties shall verify and/or obtain the current version of this document at the commencement of each project.

If an ME&S Design Package is provided for a particular project, the type, size and quantity of equipment specified shall be required for the project. This document shall be used for specific part numbers and equipment information, but not to substitute already specified equipment.

Measurement, communication, and control questions and comments can be directed to the Dominion Transmission Measurement Engineering & Support through the Dominion Transmission Project Manager. All other concerns shall also be directed to the Dominion Transmission Project Manager.

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2. General

2.1. Codes & Standards

2.1.1. All Dominion Measurement and/or Regulation Facilities shall be designed to comply with the latest edition of all applicable local, state, and federal requirements. These requirements shall include, but are not limited to, the latest edition of the following:

a. American Gas Association (AGA) b. American National Standards Institute (ANSI) c. American Petroleum Institute (API) d. American Society of Mechanical Engineers (ASME) e. American Society for Testing and Materials (ASTM) f. Code of Federal Regulations (CFR), Title 49, Part 192 g. Department of Transportation (DOT) h. Environmental Protection Agency (EPA) i. Gas Processors Association (GPA) j. Manufacturers Standardization Society (MMS) k. Minerals Management Services (MMS) l. National Fire Protection Association (NFPA) m. National Electric Code (NEC) n. Occupational Safety and Health Administration (OSHA) o. Pipeline and Hazardous Materials Safety Administration (PHMSA)

2.1.2. All Dominion Measurement and/or Regulation Facilities shall be designed to comply with the latest edition of all Dominion company standards. This includes the Design and Construction Manual, Compliance Checklist, and all application Dominion Specifications

2.1.3. DTI reserves the right to visit, inspect, review, etc. any fabricators facility to ensure that it can meet the necessary DTI requirements.

2.1.4. Within 30 days of projected shipment, the fabricator shall notify DTI Project Manager to allow for a factory acceptance of equipment.

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2.2. Required Design Data

2.2.1. The ME&S design form, located in the appendix, details design data that is required for each metering application.

2.3. Meter Station Sizing

2.3.1. Measurement facilities shall be designed to accommodate all requested and expected flow rates provided.

2.3.2. Minimum flow rates are required to account for low-flow equipment and/or applications. All fuel burning devices will require independent measurement which includes, but is not limited to, all domestic, utility and/or auxiliary fuel uses.

2.3.3. Meter selection and sizing must be approved by Dominions Measurement Engineering and Support (ME&S) Group

2.4. Drawing Approvals

2.4.1 Drawing approvals are required to be completed prior to construction. Any material ordered prior to approvals is done so at the risk of the purchasing party.

2.4.2 All drawings shall be sent to the DTI Project Manager and approved by the pertinent parties at DTI. These may include, but are not limited to:

a) Meter & Meter tube detailed piping drawing b) Building drawings c) Piping detail drawings including overheads and elevations for all piping owned or

operated by DTI. d) Bill of Material e) Electrical hazardous area classification map f) Overall Site Layout including fencing, piping, buildings, roads, poles, antennas

and all other major facilities g) Gate assembly including all piping, critical valves, measurement, and controls h) P&ID i) Electrical drawings including conduit layout, wiring schedule, and junction boxes j) Grounding plan & details k) Corrosion control plans & drawings l) Equipment layouts to include equipment in the dekatherm building and

equipment associated with metering, controls, and gas quality. m) Building foundation drawings

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3. Meter Station Site

3.1. Locations

3.1.1. The measurement facility shall be located near a public road and have an all weather access road. The facility shall be located as close to the DTI pipeline rights-of-way as practical and allow sufficient access to the pipeline. Measurement facilities shall not be constructed over the pipeline. Measurement facilities not owned by DTI shall be located off of DTI pipeline rights-of-way.

3.1.2. The measurement facility area shall be sized for ease of access and operation. Allowances shall be made to allow full size pickup truck access between both any piping and building structures. A minimum of 10 feet is required between fencing and/or piping. Noise concerns may require larger locations. If facilities are to be located on fill material sonotube piers shall not be used. In fill locations concrete beam piers shall be required.

3.1.3. A chain link fence meeting requirements of DTI drawing SF Z 3722A with a minimum of one locking vehicle gate and two locking man gates shall be erected around the measurement facility. One man gate shall be located opposite the vehicle entrance and the other beside vehicle entrance.

3.1.4. Signage identifying the facility name, operator and emergency phone number shall be posted at a location visible upon approach from the access road. All DTI security standards shall pertain.

3.1.5. The area within the fence shall be kept vegetation free through the use of ground cover, (i.e. ground stabilization fabric and gravel)

3.1.6. Electrical power for each site is required to be purchased from the local electric utility. Any other form of power for the site must be approved by the DTI Project Manager, ME&S, Gas Control, and Operations.

3.2. Structures

3.2.1. Consult field operations for structure requirements. Certain climatic conditions may require unusual needs. Gas containing buildings shall be of the walk through type.

3.2.2. Buildings are defined as a fully enclosed structure. Shelters are defined as a cover from weather.

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3.2.3. Measurement facilities shall be installed inside a building where required by DTI Operations or ME&S. If applicable, the ME&S Design Package shall determine what facilities and/or equipment is to be installed inside a building. If there is no ME&S Design Package provided, the buildings constructed over primary devices shall be sized to protect all temperature thermowells. Provisions shall be made to allow physical removal of the primary device and piping for internal inspection. All gas venting devices shall be piped to the outside, per DOT requirements.

3.2.4. For meter tube maintenance building panels shall be designed to be removable.

3.2.5. If a building is required, specifications for metal buildings will be made available. DTIs Specification 78 will be provided for Dekatherm/EGM buildings and DTIs Specification 27 will be provided for Metering or Regulation buildings.

3.2.6. No flammable material shall be used in NEC Class 1, Division 1 and 2 structures or interiors. Building manufacturer is subject to inspection and approval by DTI ME&S. Structures not meeting AGA XF0277 shall be electrically classified as Class 1, Division 1.

3.2.7. If required by Section 3.2.1, secondary measurement and control equipment shall be protected under canopy, windbreak, or walk-in type building which can be secured and protected

3.2.8. Unless authorized in writing, any customer operated equipment, heaters, regulators, controls, etc must reside outside the fence line surrounding the metering facility operated by DTI.

3.2.9. The Dekatherm building shall be temperature controlled by means of HVAC and contain the gas flow computer, gas chromatograph controller, and any other analytical equipment not suited for installation in the metering building.

3.2.10. All structure drawings to be approved by DTI ME&S prior to construction.

3.2.11. Dual classification buildings will be considered for use on a case-by-case basis. Area classification drawings will be required in addition to structural and layout drawings. Detailed requirements are available in Specification 78.

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3.3. Lighting

3.3.1. There shall be a minimum of one outdoor light installed on each building at an M&R station. Larger quantities may be required based on site conditions.

3.3.2. Exterior lights are to be wired such that a photoelectric sensor on the dekatherm building controls all exterior lighting.

3.4. Foundations

3.4.1. Refer to Section 21.3 of this specification for standard foundation drawings for metering facilities.

4. Major Station Piping

4.1. Major Piping

4.1.1. Station piping shall be designed to the following maximum velocity specifications:

Velocity (ft/m) Velocity (ft/s) New Stations 3,000 50

Upgrade to Existing Stations 5,000 83 Meter Tube 3,600 60

4.1.2. Station piping shall be designed to the following minimum wall thickness:

Nominal Diameter (In.) Wall Thickness (In.) 2 0.218 Sch. 80

2 0.203 Sch. 40 3 0.216 Sch. 40

3 0.226 Sch. 40 4 0.237 Sch. 40 6 0.280 Sch. 40 8 0.322 Sch. 40 10 0.365 Sch. 40

12 thru 24 0.375

4.1.3. Threaded piping will only be allowed for above ground applications and on piping 2-inches or smaller. All threaded pipe must adhere to DTIs pipe threading procedure. Contact DTI Project Manager for latest edition.

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4.1.4. All station piping will be pressure tested to 1.5 times its MAOP in accordance with Dominion SOP 290 and DOT 49 CFR 192. At no time will the pressure rating of the weakest component be exceeded.

4.1.5. Meter runs will have upstream and downstream isolation valves. The valves used should be full open ball valves. When available, inspection tees shall be installed upstream and downstream from the meter run.

4.1.6. All API-5L pipe must conform to the PSL2 requirements noted in API-5L.

4.2. Headers

4.2.1. Extruded headers are to be used when practical. Extruded headers are to meet the requirements of Section IV, Paragraph 4.5 of the Manual of Design and Construction Procedures.

4.2.2. Headers will be installed underground for noise reduction; headers can be installed above ground when skid mounted units are utilized. Underground headers will be designed with drainage in mind; utilizing a stinger.

4.2.3. When run staging is required to allow for greater range-ability in the measurement, a header must be used.

4.2.4. When regulation is located immediately downstream from measurement, a header must be utilized between the meter and regulation to reduce pulsation and ultrasonic noise

4.2.5. The following table will be used to determine the size of the header. The distance between runs is measured from center to center.

Meter Tube Size

Number of Meter Runs Distance Between Runs 2 3 4 5

2 4 6 3 ft 4 6 8 4 ft 6 12 16 5 ft 8 16 20 24 5 ft

10 20 24 30 6 ft 12 24 30 36 42 6 ft 16 30 36 42 48 7 ft

4.3. Flow Control & Pressure Regulation

4.3.1. Pressure regulation and/or flow control valves shall be installed downstream of the meter run isolation valve(s) and/or header. Piping is required between the metering and regulation and/or flow control valves to

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minimize acoustic error effects on the metering equipment. When ultrasonic noise is anticipated, consult Measurement Engineering & Support for recommended piping configurations.

4.3.2. Regulators and control valves shall be sized to handle the expected range of flows and the expected range of pressures at 10% and 90% of valve travel. If this condition cannot be met, additional control valves must be added using split ranged control.

4.3.3. DTI Project manager to verify, in writing, the failing position of the control valves, e.g., fail-open, fail-closed, fail-last-position

4.3.4. DTI Project manager to verify, in writing, the required type of remote control (see Section 8.6 Remote Control).

4.3.5. Noise prediction methods shall be based on ISA Standard S75.17. If noise levels exceed local, state, or federal requirements, adequate measures shall be taken to attenuate such noise to the acceptable level. For above ground piping, the predicted SPL shall not exceed 85 dBA

4.3.6. Upstream and downstream piping shall be of the same diameter or larger than all control valves and regulators with swages installed adjacent to the valve. A minimum of seven nominal pipe diameters of straight pipe shall be installed upstream and downstream of the control valve.

4.3.7. Isolation full-opening ball valves with locking provisions shall be installed upstream and downstream of all regulator and control valve runs

4.3.8. Both a bleed valve and blow-down valve shall be installed between the regulator/control valve and any isolation valve, upstream or downstream. Bleed valves shall be installed within any section which may be isolated. Blow-down valve shall be piped outside of regulation building

4.3.9. A bypass shall be installed around all regulators and control valve runs unless two or more are installed in parallel. Taps shall be provided on the bypass for pressure sensing and instrument supply/power gas. Locking devices shall be installed on all bypass valves

4.3.10. Operating temperature range shall be considered. If necessary, adequate heating facilities shall be installed to prevent regulator freezing or other control issues. Each high-pressure instrument supply line requires approved heater

4.3.11. Flow control and pressure regulation systems shall have filtered and dried sources of instrument supply/power gas

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4.3.12. Each pressure control device shall have independent sensing lines located downstream of downstream isolation valves

4.3.13. At measurement facilities utilizing flow control or pressure regulation that require positive shut-off, a ball valve and actuator shall be installed. Typically, this valve and actuator will be installed on the first meter run

4.3.14. When multiple control valves are present or multiple input signals to a single control valve, then an independent inst. supply is required for each device.

4.4. Meter Run Piping & Tubing Configurations

4.4.1. All meters must have a bypass unless otherwise approved by Dominion Measurement Engineering & Support. This bypass can be a piece of pipe comparable in flow ability to the adjacent meter. If multiple meter runs are required, no bypass will be required (does not include low-flow measurement).

4.4.2. All meter must have a blowdown port; per the drawing. If the meter run in located inside a building, the port should be vented outside.

4.4.3. All meters will have direct mount pressure transducers. Other applications will be required to be approved in writing from ME&S.

4.4.4. All meter designs will follow the standard meter drawings located in the drawings section of this specification.

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5. Overpressure Protection

5.1. General

5.1.1. Overpressure protection is required anywhere there is a mismatch in MAOP and/or per the requirements of CFR 192. Overpressure protection can be in the form of a combination of regulators and relief valves, or high-pressure shutdowns at the compressors and relief valves, or a monitor set of regulation.

5.1.2. For connections coming onto DTIs system, there shall be no mismatch of MAOP across the M&R Facility, unless otherwise specified in the operating agreement.

5.1.3. If freezing is a concern, an approved heater shall be required.

5.2. Relief Valves as Overpressure Protection

5.2.1. If relief valves are specified for overpressure protection, they shall be installed at the inlet of the M&R facility before measurement.

5.2.2. Relief valve(s) installed for over-pressure protection will be set at a pressure designated by DTI Project Manager.

5.2.3. Only relief valves approved by DTI shall be utilized.

5.2.4. The relief valve(s) will be installed on a lockable full port isolation valve with test connections located between the isolation valve and relief valve

5.2.5. Relief valve(s) will include a vent per DOT requirements with a rain cap on the outlet of each vent

5.3. Pressure Regulators as Overpressure Protection

5.3.1. The monitor and worker regulators valves will each have a sensing line and tap that is independent of the other. Both located downstream a minimum of 8 to 10 pipe diameters from the outlet of the last regulator in the series and outside downstream isolation valve.

5.3.2. Each sensing and supply line shall be installed with a lockable full port isolation valve.

5.3.3. The use of fail open or fail closed will have to be determined on a case-by-case basis. DTI Project manager to verify, in writing, fail-open, fail-closed or fail-last-position.

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6. Primary Measurement

6.1. Ultrasonic Meters

6.1.1. At a minimum, the Ultrasonic Meter (USM) and associated meter tube specifications shall adhere to the latest edition of AGA Report No. 9, Measurement of Gas by Multipath Ultrasonic Meters and Dominions Standard Ultrasonic Meter Procurement Drawing.

6.1.2. The USM type and nominal tube size shall be approved by Dominions Measurement Engineering and Support (ME&S) Group. The design shall be based on the following criteria:

6.1.2.1. Maximum Meter Capacity: A maximum design gas velocity of sixty (60) feet per second (fps) will be used with the maximum peak hourly flow at the minimum pressure at the meter

6.1.2.2. Minimum Meter Capacity: A minimum design gas velocity of three (3) fps will be used with the minimum peak hourly flow at the maximum pressure at the meter.

6.1.3. The pressure tap on the meter body shall be utilized for static pressure readings.

6.1.4. To minimize acoustic effects on measurement, flow control valves and/or pressure regulation shall be downstream of the ultrasonic measurement. A separate header is required downstream of measurement for the control valves and/or regulation.

6.1.5. Calibration Requirements

6.1.5.1. All ultrasonic meter run assemblies shall be flow calibrated at a facility approved by Dominions ME&S Group.

6.1.5.2. Bidirectional ultrasonic meter run assemblies shall be flow calibrated in both directions.

6.1.5.3. During the flow calibration, the ultrasonic meter run assembly shall include all upstream and downstream piping, fittings, flow conditioner(s), spacer plates and thermowells. Once calibrated, the meter run assembly shall not be disassembled without written permission by Dominion Transmissions Measurement Engineering & Support engineers.

6.1.5.4. The calibration shall consist of a minimum of eight test flow points and three verification flow points. Unless otherwise specified by Dominions ME&S Group upon request, the flow points shall be, as close as possible,

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to 1, 3, 10, 20, 30, 60, 80, and 100 fps. Verification points shall be, as close as possible, to 3, 30, 60 fps.

6.1.5.5. A flow calibration certification report shall be provided by the flow calibration facility. The certification report shall include:

6.1.5.5.1. All data points tested

6.1.5.5.2. Configuration files from the meter showing as found and as left configurations

6.1.5.5.3. A summary of the calibration findings stating the maximum error, offset, linearity, repeatability, resolution, zero flow reading, etc.

6.1.6. Three sets of complete documentation shall be provided in hardcopy. The same document set shall be provided electronically. This documentation shall include: fabrication records and drawings, flow calibration certification and records, user manuals, etc. Two sets shall be provided to the ME&S Group and one set shall be provided to Project Management

6.2. Orifice Meters

6.2.1. At a minimum, Orifice Meters and associated meter tube specifications shall adhere to the latest edition of AGA Report No. 3, Orifice Metering of Natural Gas and Other Related Hydrocarbon Fluids and Dominions Standard Orifice Meter Procurement Drawing

6.2.2. The Orifice Meter type and nominal tube size shall be approved by Dominions Measurement Engineering and Support (ME&S) Group. The design shall be based on the following criteria:

6.2.2.1. Maximum Meter Capacity: A maximum design pressure differential of one-hundred (100) inches of water column will be used with the maximum peak hourly flow at the minimum pressure at the meter. The maximum allowed beta ratio shall be 0.6.

6.2.2.2. Minimum Meter Capacity: A minimum design pressure differential of ten (10) inches of water column will be used with the minimum peak hourly flow at the maximum pressure at the meter. The minimum allowed beta ratio shall be 0.2

6.3. Turbine Meters

6.3.1. At a minimum, Turbine Meters and associated meter tube specifications shall adhere to the latest edition of AGA Report No. 7, Measurement of

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Natural Gas by Turbine Meters and Dominions Standard Turbine Meter Procurement Drawing.

6.3.2. The Turbine Meter type and nominal tube size shall be approved by Dominions Measurement Engineering and Support (ME&S) Group. The design shall be based on the following criteria:

6.3.2.1. Maximum Meter Capacity: The maximum peak hourly flow at the minimum pressure located at the meter; in accordance with the Manufacturers published data.

6.3.2.2. Minimum Meter Capacity: The minimum peak hourly flow at the maximum pressure located at the meter; in accordance with the Manufacturers published data.

6.3.2.3. Turbine meters are required to be calibrated by the manufacturer at both atmospheric pressure and the designed operating pressure. The Calibration sheets must be located on-site with the meter.

6.3.2.4. Turbine meters smaller than four (4) inches shall not be used.

6.3.2.5. Auto-Adjust Turbine Meters shall be used only for 4-inch, 6-inch, 8-inch and 12-inch applications. High-capacity AAT Meters are not acceptable.

6.3.2.6. Automatic oilers will be used for Turbine Meters when applicable

6.3.2.7. The pressure tap on the meter body shall be utilized for static pressure readings.

6.4. Coriolis Meters

6.4.1. At a minimum, Coriolis Meters and associated meter tube specifications shall adhere to the latest edition of AGA Report No. 11, Measurement of Natural Gas by Coriolis Meters and Dominions Standard Coriolis Meter Procurement Drawing.

6.4.2. The type, quantity, and size shall be approved by Dominions ME&S group.

6.4.3. Pressure transmitter connections, test wells, and sample probes shall be installed upstream of the Coriolis meter.

6.4.4. The integral RTD on the Coriolis meter may be used for temperature measurement.

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6.4.5. Provisions shall be made to ensure any natural gas used in sonic nozzle testing can be vented outside of the meter building.

6.4.6. Coriolis meters shall be installed in buildings such that removal and installation does not require any disassembly of the meter building.

6.4.7. ME&S shall be consulted for the orientation of the Coriolis meter.

6.5. Positive Displacement Meters

6.5.1. Rotary Meters

6.5.1.1. At a minimum, Rotary Meters and associated meter tube specifications shall adhere to the latest edition of Dominions Standard Rotary Meter Procurement Drawing.

6.5.1.2. The Rotary Meter type and nominal tube size shall be approved by Dominions Measurement Engineering and Support (ME&S) Group. The design shall be based on the following criteria:

6.5.1.2.1. Maximum Meter Capacity: The maximum peak hourly flow at the minimum pressure at the meter; in accordance with the Manufacturers published data.

6.5.1.2.2. Minimum Meter Capacity: The minimum peak hourly flow at the maximum pressure at the meter; in accordance with the Manufacturers published data.

6.5.1.3. Rotary Meters will not normally be used, unless flow rates and pressure make them a practical choice.

6.5.1.4. The pressure tap on the meter body shall be utilized for static pressure readings.

6.5.1.5. Provisions must be made in the meter tube, or loop, for the meter to be tested by either a critical flow prover or transfer prover. This will require an upstream and downstream proving tap that is absent of any obstructions, i.e., required restrictor plate. The proving section will also be required to be purged prior to testing, therefore it is necessary that the testing section incorporate valves for blow down and purge while the bypass is operational.

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6.5.2. Diaphragm Meters

6.5.2.1. At a minimum, Diaphragm Meters and associated meter tube specifications shall adhere to the latest edition of Dominions Standard Diaphragm Meter Procurement Drawing.

6.5.2.2. The Diaphragm Meter type and nominal tube size shall be approved by Dominions Measurement Engineering and Support (ME&S) Group. The design shall be based on the following criteria:

6.5.2.2.1. Maximum Meter Capacity: The maximum peak hourly flow at the minimum pressure at the meter; in accordance with the Manufacturers published data.

6.5.2.2.2. Minimum Meter Capacity: The minimum peak hourly flow at the maximum pressure at the meter; in accordance with the Manufacturers published data.

6.5.2.3. Diaphragm Meters will not normally be used, unless flow rates and pressure make them a practical choice.

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7. Secondary Measurement Devices

7.1. Transmitters

7.1.1. Each primary measurement device shall have an approved static gauge pressure and temperature transmitter. See approved list.

7.1.2. Electrical conduit must be run in such a manner which will allow for easy removal of individual transmitters for service repair

7.1.3. A conduit seal is required at entry point of unclassified building, regardless of the classification at the opposite end of the conduit

7.1.4. Transmitters shall be direct-mounted to the orifice fitting. The orientation of the transmitters shall be such that all access covers can be easily removed without having to rearrange tubing or conduit.

7.1.5. Transmitter tubing shall be isolated from the cathodic protection

7.1.6. Tubing lines shall be adequately supported using stands or tubing trays and kept to a minimum run length.

7.1.7. Transmitter wiring shall be 18 AWG shielded twisted pair per ME&Ss wiring schedule. The shield shall be grounded at GFC end only (see Grounding section of this document).

7.1.8. If the application is approved in writing, buried tubing must be rated for underground installation and shall be continuous and without fittings.

7.1.9. Isolation valves shall be provided at the metering taps and shall be full opening ball valves

7.1.10. Pressure transmitters shall be installed with appropriate valving to allow isolation and a valve for testing and venting

7.1.11. Temperature transmitters shall be mounted on the meter run and installed with appropriate conduit unions that allow for easy removal. Flexible conduit connectors to the temperature transmitter are required.

7.1.12. Antiseize shall be used on temperature transmitter RTD sensors to prevent galling.

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7.1.13. Per the meter drawing, a thermometer well shall be installed and located adjacent to the temperature transmitter thermowell for testing purposes

7.1.14. Approved Flow Computers that have integral transmitters, shall be isolated from the meter run and sources of cathodic protection current

7.1.15. Installations must be compliant with all hazardous area classification installation requirements.

7.1.16. DTI does not currently support the use of stand-alone multi-variable transmitters.

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8. Tertiary Measurement Device

8.1. Installation Criteria

8.1.1. This specification applies to both GFCs and electronic volume correctors and shall be in compliance with API Manual of Petroleum Measurement Standards Chapter 21 Section 1.

8.1.2. All metering facilities, both delivery and receipt, require Electronic Flow Measurement (EFM) equipment (see Approved EFM Equipment) with the RTU having direct communications to DTIs SCADA system in Clarksburg, WV prior to placing the facility into operation.

8.1.3. GFC shall be specified by DTIs Measurement, Engineering and Support Department (ME&S) and utilize DTIs proprietary flow measurement and control application software that conforms to the latest AGA and API standards.

8.1.4. The installation of EFM equipment shall conform to DTI standards and specifications. All drawings, schematics, and P&ID documents related to electronic gas measurement and control must be approved by DTIs Measurement, Engineering and Support department prior to the start of construction. DTI reserves the right to approve the completed assemblies at the fabricators facility prior to shipment to the location.

8.1.5. Each M&R Facility will require remote shutoff capabilities. (see Section 8.6 - Remote Control)

8.1.6. Approved battery back-up power shall be supplied to maintain the GFC for a minimum of 72 hours.

8.2. Gas Flow Computer (GFC) Types

8.2.1. DTIs Measurement Engineering & Support department will determine the GFC type on a case by case basis from the list in the Approved Measurement Operating Equipment section.

8.3. EFM Grounding

8.3.1. The EFM system shall be electrically isolated from the pipeline and cathodic protection and the resistance between the instrumentation and earth ground shall be maintained at a maximum of 5 ohms.

8.3.2. Drawings for a ground system layout and details are provided in this document (DS-X7446J & DS-X7446K)

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8.3.3. All wiring and terminations shall be done so as to not produce ground loops of any type.

8.3.4. All chassis grounds on the EFM equipment shall be isolated from any metal support or structure (the use of nylon screws and washers are acceptable)

8.3.5. Power supply return shall be isolated from the power common to prevent ground loops

8.3.6. A copper ground buss bar shall be used and connected directly to the grounding grid using #2/0 copper wire. All transmitter shields and GFC chassis grounds shall be connected to this bus bar.

8.3.7. The negative (ground) side of the 24 volt battery charger shall be connected to the copper ground bus bar using #6 AWG copper wire. The battery charger chassis ground and battery charger 24V RET should be isolated internally.

8.4. Isolation & Intrinsically Safe Wiring

8.4.1. Electronic equipment shall be isolated from the pipeline and be in compliance with DOT 49 CFR Part 192. No insulating flange gaskets, insulating tubing unions, or like devices shall be installed inside measurement buildings that are classified hazardous area locations (NEC Class 1, Division 1 or 2) unless arc suppression devices are properly employed.

8.5. Interfacing

8.5.1. All analog and/or digital signals to be shared from the RTU shall be isolated by means of a signal isolation device provided by the requesting party and approved by DTI.

8.5.2. Any serial communication links to the EFM equipment shall be through a read-only port and consist of an isolation device provided by the requesting party and approved by DTI.

8.5.3. The design for sharing any data is limited to information purposes only and a separate, executed Data Sharing Agreement is required

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8.6. Remote Control

8.6.1. On/Off Control

8.6.1.1. On/Off Remote Control requires, at a minimum, control of an isolation valve that will shut the flow of gas off at the facility.

8.6.1.2. Actuator shall be from approved equipment list and a dual solenoid fabrication is required.

8.6.1.3. Independent opened and closed indications shall be utilized by the RTU to detect valve position (opened, closed, transition, and failed).

8.6.2. Flow Control

8.6.2.1. The 6-30 psi output for valve control will be supplied by a Remote Set or DVC (see Approved EFM Equipment) and controlled by the RTU utilizing either a 4-20mA signal or two independent 24 Vdc discrete outputs, A 4-20 mA signal from the valve controller shall be utilized by the Flow Computer to indicate position. Standard modes of control consist of Pressure, Flow, Pressure with Flow Override, or Flow with Pressure Override

8.7. Electronic Run-Switching

8.7.1. Run-switching is On/Off Control that requires control of an isolation valve that will shut the flow of gas off a secondary measurement run

8.7.2. Actuator shall be from approved equipment list and a dual solenoid fabrication is required

8.7.3. Independent opened and closed indications shall be utilized by the RTU to detect valve position (opened, closed, transition, and failed).

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9. Tubing

9.1. Size

9.1.1. Unless granted waiver by DTI ME&S all measurement facility tubing shall be as described in 9.1

9.1.2. Where orifice meters are in use without direct mount manifolds the static pressure tubing shall be 3/8-inch OD. Differential pressure tubing shall be 1/2-inch OD.

9.1.3. All sensing and control tubing shall be 3/8-inch OD

9.1.4. Gas Chromatograph tubing shall be 1/4-inch or 1/8-inch OD and heatraced the entire length of the run, from probe outlet to Gas analyzing equipment. This tubing shall be referred to as sample line. Diameter to be determined by refresh rates.

9.2. Installation

9.2.1. Underground gas chromatograph sample line shall be protected by running through 4-in heavy wall PVC pipe. Any turns shall be made using long radius or 45 degree fittings separated by 2 ft lengths of straight PVC. No short radius elbows are permitted.

9.2.2. Tube fittings shall be commensurate with tubing and suitable therewith. Buried tube fittings are not permitted. Tubing must slope towards the source. Preference is at least 1/4-inch per foot.

9.2.3. Tubing shall be adequately supported by use of trays or clips and kept at a minimum run length.

9.2.4. Tubing requiring isolation from cathodic protection shall have electrically insulated fittings

9.3. Material

9.3.1. All tubing shall be .0035 wall thickness 316 SS seamless and fully annealed, ASTM A-269, Specification for Seamless and Welded Austenitic Stainless Steel Tubing for General Service

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10. Gas Sampling

10.1. Sampler Requirements

10.1.1. Composite samplers may only be used upon application review and approval by DTI ME&S. Each application shall be reviewed on a case by case basis.

10.1.2. A heated enclosure for the composite sampler shall be installed anywhere ambient temperatures may be within 10 deg F of the hydrocarbon dew point.

10.1.3. Sample lag-time should be kept to a minimum. Installations with longer sample tubing runs will require a speed-loop. Determination of need will be performed by DTI ME&S. Anywhere possible, sample tubing shall slope towards the sample point

10.2. Sample Probe

10.2.1. Sample probes will be insertion type and filtered at the probe tip. Probes will be on straight runs of pipe and inserted from the top into the least turbulent flowing stream to a depth allowing samples to be taken from the middle third of the stream. Located at the analyzer(s), sample streams shall contain a liquid block type membrane filter per approved equipment list

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11. Gas Chromatographs

11.1. Chromatograph Location Requirements 11.1.1. Unless specified elsewhere Gas Chromatographs shall be installed at

metering facilities designed for gas flow volumes of 1 mmscfd or greater. Situations where compliance to gas quality standards or impact to pipeline systems is a concern Gas Chromatographs may be required for design volumes less than 1 mmscfd. Gas Chromatographs are required for all bi-directional custody transfer metering facilities and at metering locations used for inter-company zone balancing.

11.2. Chromatograph Installation Requirements 11.2.1. Gas Chromatographs shall consist of an approved controller and

analyzer. Installation shall be in accordance with DTI standard methodology. Each analyzer shall be on a dedicated AC circuit having the ability to be de-energized at a switch or circuit breaker. No other analyzer, heat trace etc shall share the analyzer circuit.

11.2.2. When in use calibration gas cylinders shall installed with a heating blanket and kept insulated from the building floor. Calibration gas tubing run between the calibration gas cylinder and analyzer shall be -inch 316 SS seamless, insulated and heat traced.

11.3. Tubing 11.3.1. Sample lag-time should be kept to a minimum. Installations with longer

sample tubing runs will require a speed-loop. Determination of need will be performed by DTI ME&S. Anywhere possible, sample tubing shall slope towards the sample point.

11.3.2. Tubing valves installed in the sample stream tubing must be full port ball type.

11.3.3. To reduce possible hydrocarbon condensation, sample stream tubing shall be -inch diameter heat traced, per section 9 of this document.

11.3.4. All vent tubing shall be run to the exterior of the building and above the eaves to meet, or exceed, any applicable codes and/or standards.

11.3.5. GC vent tubing shall be a minimum of -inch diameter. Separate vents shall be provided for the measure and sample vents.

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11.4. Sample Probe 11.4.1. Sample probes will be insertion type and filtered at the probe tip. Probes

will be on straight runs of pipe and inserted from the top into the least turbulent flowing stream to a depth allowing samples to be taken from the middle third of the stream.

11.4.2. Located at the analyzer(s), sample streams shall contain a liquid block type membrane filter per approved equipment list.

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12. Odorization

12.1. Odorization is not to be installed unless required to meet the CFR, Title 49, Part 192. When installed, the following requirements must be met:

12.1.1. The odorant must enter the gas stream downstream of the measurement and regulation.

12.1.2. Odorizing equipment should be located so as not to be in the prevailing upwind position of any populated area, as practical. If not practical, odorant shall be placed in separate building.

12.2. The measurement used to control any necessary odorization shall be reviewed and approved by Dominions ME&S Group.

12.3. Dominion does not odorize natural gas for their customers.

13. Gas Quality

13.1. The quality of natural gas for facilities interconnecting with Dominion must comply with the limitations and standards set forth by Dominions FERC Tariff.

13.2. On-line gas quality equipment shall be installed at all pipeline-to-pipeline transfer or input facilities, including but not limited to producer interconnects, gathering systems, receipt points, etc. Please consult Dominions ME&S Group for gas quality equipment requirements that may include, but are not limited to:

13.2.1. Gas Chromatograph

13.2.2. Moisture Analyzer

13.2.3. Oxygen Analyzer

13.2.4. Hydrogen Sulfide Analyzer

13.3. Gas Quality Assurance Valves shall be installed at all producer interconnects and receipts points. This automatic, or remotely operated, shut-in valve will be after measurement and sample locations. A remotely operated station shut-in valve can serve as the Gas Quality Assurance Valve.

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14. Other Considerations

The following equipment specifications are available upon request from the DTI Project Manager. This equipment should be considered when designing a DTI M&R Facility.

14.1. Fuel Gas

14.1.1.1. Fuel gas tap locations shall be as described below:

14.1.1.1.1. DTI owned facilities Upstream of discharge metering. 14.1.1.1.2. Customer owned facilities Upstream of DTI receipt metering,

downstream of DTI delivery metering.

14.2. Dehydration

14.2.1.1. Metering facilities where dehydration systems are located upstream may require a filter/separator to reduce liquid accumulation in the interconnect piping. These cases will be review on a individual basis. Chloride containing compounds cannot be used for removal of entrained water.

14.2.1.2. At all DTI receipt points instrument supply and fuel gas taps shall be upstream metering.

14.3. Heating

14.3.1.1. Gas heating equipment shall be located a minimum of 25 feet from Class 1 Division 2 area

14.3.1.2. Heater fuel taps shall be

14.3.1.2.1. DTI owned facilities Upstream of delivery metering 14.3.1.2.2. Customer owned facilities Upstream of DTI receipt metering,

downstream of DTI delivery metering.

14.4. Filter and Separation

14.4.1.1. At DTI receipt locations, filter separators with liquid level control shall be installed upstream of metering facilities. If customer owned dehydration and separation equipment is a significant distance from the receipt point and pipeline drip or condensation is possible a filter separator will be required at the inlet to the metering facility.

14.4.1.2. DTI delivery facilities may require filter separator equipment. DTI or the receiving company may make a determination during construction planning.

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15. Standard Wiring & Electrical Requirements

15.1. General Electric Requirements

15.1.1. All electrical work shall conform to the latest revision of the National Electric Code (NEC).

15.1.2. All work in explosion proof area to be installed to meet the latest revision of the NEC.

15.1.3. An adequate power source must be available at the measurement site as per 3.1.6. If the power source is deemed inadequate, or unreliable, DTI retains the right to install a properly sized generator on-site for back-up power generation.

15.1.4. A main power disconnect shall be installed prior to the breaker box at each site such that DTI personnel have access to the disconnect.

15.1.5. All lighting, receptacles, exhaust fans, etc. in building to have #12 AWG Ground.

15.1.6. Each meter building shall have, at a minimum, one (1) Class 1, Div. 1 rated receptacle installed.

15.1.7. All underground conduit to be PVC coated,, Pittsburgh Standard Conduit Co. Plasti-Bond or Ocal Blue

15.1.8. All buried conduit to be buried 2'-0" below grade

15.1.9. All conduit leaving hazardous area to be sealed. The seal shall be the first fitting out of the ground when the hazardous area boundary is at the ground penetration.

15.1.10. Each device in a rated area shall be sealed per NEC requirements unless the device is labeled as not requiring a seal.

15.1.11. PVC coated conduit to have coating extend a minimum of 4" above concrete or grade.

15.1.12. All 3-wire to be stranded type MTW copper, 600 Volt rating. All others to be type THWN copper, 600 Volt rated.

15.1.13. All flex connectors in Class 1, Div. 1 area to be type ECLK. All flex connectors in Class 1, Div. 2 area to be Type LFMC.

15.1.14. For a Rotary Meter, the wires shall be ran to the Barrier in the Dekatherm Building per the following information: Turck Barrier - IM1-22EX-T

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15.2. General Grounding Requirements

15.2.1. All below grade wire splices or taps shall be made using a cadweld or equal process. Splices and taps shall be insulated by self-vulcanizing rubber tape built-up to twice the original insulation thickness, then painted using Skitchkote or equal, and finally coated with friction tape.

15.2.2. Grounded cables shall be buried a minimum of 18 below grade

15.2.3. Main grounding grid to be #2/0 AWG stranded, green insulated THHN/THWN

15.2.4. All ground wire bends shall be of sweeping radius to avoid sharp bends.

15.2.5. Ground wire turns shall follow main conduit runs. Ground wire may be laid in the same trench as the conduit.

15.2.6. All ground rods to be 3/4" by 10 feet in length and constructed of galvanized steel coated to a minimum of 10 mil.

15.2.7. Refer to drawings DS-X7446J & DS-X7446K in the drawings section of this document.

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15.3. ME&S Typical Wiring Table

The following Typical Wiring Table should be considered a template. This table lists most of the typical gas measurement devices found at DTI Measurement & Regulation (M&R) and Compressor Stations. If a device listed is not on the required materials list for a specific project, it should be disregarded. Also, if there are two (2) or more of a certain device, the table will need to be multiplied by the number of devices.

# Device Type (Ea.) Device Desc.

Conductor/Wire CondType

Location*

Qty Type/Size Ins. From To From To 1 Ultrasonic

Meter (USM)

Comm. 1 4pr Belden 1592A #24 AWG, Twisted (RS-232/485 in meter head)

Shld RGS USM M&R Jnct. Box

M&R Jnct. Box

Flow Computer

2 USM Ethernet 1 4pr Belden 1592A #24 AWG, Twisted


M&R Jnct. Box

Flow Computer

3 USM Pulse Inputs / Outputs & Validity

5 1pr West Penn #293#18 AWG, Twisted


M&R Jnct. Box

Flow Computer

4 USM Test Cable

1 4pr Belden 1592A #24 AWG, Twisted (1' wound in Jnct. Box)

Shld RGS Jnct. Box @ Meter

M&R Jnct. Box

M&R Jnct. Box

Flow Computer

5 USM DC Power



M&R Jnct. Box

24V DC Dist. Panel

6 Auto-Adjust Turbine Meter (AAT)

Pulse Inputs / Outputs


Shld RGS AAT M&R Jnct. Box

M&R Jnct. Box

Flow Computer

7 AAT Test Cable



M&R Jnct. Box

M&R Jnct. Box

Flow Computer

8 Orifice Meter

Test Cable



M&R Jnct. Box

M&R Jnct. Box

Flow Computer

9 Coriolis Meter

Pulse Outputs


Shld RGS Coriolis M&R Jnct. Box

M&R Jnct. Box

Flow Computer

10 Coriolis Meter

Test Cable


Shld RGS Coriolis M&R Jnct. Box

M&R Jnct. Box

Flow Computer

11 Rotary Meter

IMAC Pulser


Shld RGS Pulser @ Meter

M&R Jnct. Box

M&R Jnct. Box

Flow Computer

12 Rotary Meter

Test Cable



M&R Jnct. Box

M&R Jnct. Box

Flow Computer

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Location*

Qty Type/Size Ins. From To From To 13 Diaphragm

Meter RVP Pulser


Shld RGS Pulser @ Meter

M&R Jnct. Box

M&R Jnct. Box

Flow Computer

14 Diaphragm Meter

Test Cable



M&R Jnct. Box

M&R Jnct. Box

Flow Computer

15 Transmitter Pressure 2 1pr West Penn #293#18 AWG, Twisted

Shld RGS Trans-mitter

M&R Jnct. Box

M&R Jnct. Box

Flow Computer

16 Transmitter Temp. 2 1pr West Penn #293#18 AWG, Twisted


M&R Jnct. Box

M&R Jnct. Box

Flow Computer

17 Transmitter DP 2 1pr West Penn #293#18 AWG, Twisted


M&R Jnct. Box

M&R Jnct. Box

Flow Computer

18 Gas Chromato-graph (GC)

Power to GC

3 #10 AWG, THWN-2 Thwn-2 RGS GC Analyzer

AC Switch @ Analyzer


AC Panel

19 GC Comm. 1 Belden 9947CMG15C22 15 Conductor

Shld RGS GC Analyzer

M&R Jnct. Box

M&R Jnct. Box

GC Controller

20 GC Heat-Traced Tubing

2 1/4" Seamless SST Self-Regulated 5W Heat Traced Tubing

Nickel Plated

- Sample Loc.

GC Analyzer

21 GC Cal. Gas Heat Blanket

3 #12 AWG, THWN-2 Thwn-2 RGS Blanket

AC Switch @ Blanket

AC Switch @ Blanket

AC Panel

22 GC Test Cable

1 4pr Belden 1592A #24 AWG, Shielded, Twisted

Shld RGS Jnct. Box @ GC

GC Controller

23 Moisture Analyzer (H2O)

Input / Output

3** 1pr West Penn #293#18 AWG, Twisted

Shld RGS H2O Analyzer

Flow Computer

24 H2O Power to Analyzer

3 #12 AWG, THWN-2 Thwn-2 RGS H2O Analyzer



AC PANEL

25 H2O Heat-Traced Tubing


Nickel Plated

- Sample Loc.

(if diff. from GC)

H2O Analyzer

26 H2O Test Cable

1 4pr Belden 1592A #24 AWG, Twisted

Shld RGS Jnct. Box @

Analyzer

Flow Computer

27 Oxygen Analyzer (O2)

Input / Output


Shld RGS O2 Analyzer

Flow Computer

28 O2 Power to Analyzer

3 #12 AWG, THWN-2 Thwn-2 RGS O2 Analyzer



AC Panel

29 O2 Heat-Traced Tubing


Nickel Plated

- Sample Location(if diff.

from GC)

O2 Analyzer

30 O2 Test Cable



Analyzer

Flow Computer

31 Hydrogen Sulfide Analyzer (H2S)

Input / Output


Shld RGS Analyzer Flow Computer

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Location*

Qty Type/Size Ins. From To From To 32 H2S Power to

Analyzer 3 #12 AWG, THWN-2 Thwn-2 RGS H2S

Analyzer AC

Switch @ Analyzer


AC Panel

33 H2S Heat-Traced Tubing


Nickel Plated

- Sample Location(if diff.

from GC)

H2S Analyzer

34 H2S Test Cable



Analyzer

Flow Computer

35 Remote-Set Regulator

Control 4 1pr West Penn #293#18 AWG, Twisted

Shld RGS Remote Set

M&R Jnct. Box

M&R Jnct. Box

Flow Computer

36 I/P Controller


Shld RGS I/P Cont. M&R Jnct. Box

M&R Jnct. Box

Flow Computer

37 Valve-Operator


Shld RGS Valve Operator

M&R Jnct. Box

M&R Jnct. Box

Flow Computer

38 Building Power

Power TBD #10 AWG Shld RGS AC Panel M&R AC Jnct. Box

39 Spare Conduit

Spare Conduit

n/a n/a n/a RGS DTH Building

M&R Building

**Dual Channel: If a dual channel moisture analyzer is procured, then the quantity requirement changes to six.

15.4. Junction Boxes

15.4.1. All junction boxes shall be located inside meter buildings.

15.4.2. MJB1 shall be at least 24x20x8. Larger sizes may be required depending on equipment type and quantity for each project. Junction box to be NEMA rated to provide a degree of protection against the ingress of water.

15.4.3. MJB2 shall be at least 12x12x8. Larger sizes may be required depending on total equipment required. Junction box to be NEMA rated to provide a degree of protection against the ingress of water.

15.4.4. If a dual classification building is used, the wiring will be pulled from the classified side to the unclassified side without passing through a J-box.

15.4.5. If the meter building and instrumentation is field installed, the junction boxes may not be required. Consult ME&S for final determination.

15.4.6. The DIN rail mounted terminals of the same numbering to be located in the Dekatherm building. All wiring from device to terminal to be labeled with the terminal number. Spare cables may be labeled with an independent cable number.

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15.5. ME&S Typical Terminal Strip Labeling Table

The following Typical Terminal Strip Tables should be considered to be standard numbering for new DTI M&R Stations. This table lists most of the typical gas measurement devices found at DTI Measurement & Regulation (M&R) and Compressor Stations. If a device listed is not on the required materials list for a specific project, it should be disregarded. Also, if additional devices are needed, but not covered below, then those terminals should be added and numbered in a similar fashion to the table below.

MJB1 - DC only junction box inside the meter building. All wiring from device to terminal to be labeled with the terminal number. If a cable is a spare, then it shall be labeled at each end with a unique cable number.

# 4-20 Analog Terminal Strip ATS1



101 Pressure Run 1 PR1 + 117 Temperature Misc 1 TM1 + 133 Spare +102 Pressure Run 1 PR1 - 118 Temperature Misc 1 TM1 - 134 Spare - 103 Pressure Run 2 PR2 + 119 Temperature Misc 2 TM2 + 135 Remote Set/I-P Feedback 1 FB1 +104 Pressure Run 2 PR2 - 120 Temperature Misc 2 TM2 - 136 Remote Set/I-P Feedback 1 FB1 - 105 Pressure Run 3 PR3 + 121 Moisture Analyzer 1 MA1 + 137 Remote Set/I-P Feedback 2 FB2 +106 Pressure Run 3 PR3 - 122 Moisture Analyzer 1 MA1 - 138 Remote Set/I-P Feedback 2 FB2 - 107 Pressure Misc 1 PM1 + 123 Oxygen Analyzer 1 OA1 + 139 Remote Set/I-P Feedback 3 FB3 +108 Pressure Misc 1 PM1 - 124 Oxygen Analyzer 1 OA1 - 140 Remote Set/I-P Feedback 3 FB3 - 109 Pressure Misc 2 PM2 + 125 H2S Analyzer 1 HA1 + 141 I-P Control Signal 1 IP1 +110 Pressure Misc 2 PM2 - 126 H2S Analyzer 1 HA1 - 142 I-P Control Signal 1 IP1 - 111 Temperature Run1 TR1 + 127 Spare 143 I-P Control Signal 2 IP2 +112 Temperature Run1 TR1 - 128 Spare 144 I-P Control Signal 2 IP2 - 113 Temperature Run 2 TR2 + 129 Spare 145 I-P Control Signal 3 IP3 +114 Temperature Run 2 TR2 - 130 Spare 146 I-P Control Signal 3 IP3 - 115 Temperature Run 3 TR3 + 131 Spare 116 Temperature Run 3 TR3 - 132 Spare

# GC Interconnect Term. GCTS1

# Ethernet RS-485 (Use RJ-45 Connectors)

# Misc. Test Cables (Label but do not wire to Terminal Block)

11 Function Code 1 40 Comm A 80 Belden 1592A (Meter) 12 Function Code 2 41 Comm B 81 Belden 1592A (Meter) 13 Function Code 4 42 Comm C 82 Belden 1592A (Meter) 14 Function Code 8 43 Comm D 83 Belden 1592A (Meter) 15 Function Code Strobe 44 Comm E 84 Belden 1592A (GC) 16 Common Function Codes 45 Comm F 85 Belden 1592A (H2O) 17 Auto Zero 46 Comm G 86 Belden 1592A (O2) 18 Preamp Gain Channel 1 87 Belden 1592A (H2S) 19 Preamp Gain Channel 2 20 Preamp Gain Channel 3 21 Preamp Gain Channel 4 22 Common Preamp Gain 23 Alarm Function 24 Spare 25 Spare

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MJB1 Continued

# Digital Terminal Strip DTS1 # Digital Terminal Strip DTS1 201 Meter 1 Validity + 247 Spare + 202 Meter 1 Validity - 248 Spare - 203 Meter 2 Validity + 249 Valve 1 Open Status V1OS + 204 Meter 2 Validity - 250 Valve 1 Open Status V1OS - 205 Meter 3 Validity + 251 Valve 1 Close Status V1CS + 206 Meter 3 Validity - 252 Valve 1 Close Status V1CS - 207 Misc 4 Validity + 253 Valve 2 Open Status V2OS + 208 Misc 4 Validity - 254 Valve 2 Open Status V2OS - 209 Moisture Analyzer 1 Validity + 255 Valve 2 Close Status V2CS + 210 Moisture Analyzer 1 Validity - 256 Valve 2 Close Status V2CS - 211 Oxygen Analyzer 1 Validity + 257 Valve 3 Open Status V3OS + 212 Oxygen Analyzer 1 Validity - 258 Valve 3 Open Status V3OS - 213 H2S Analyzer 1 Validity + 259 Valve 3 Close Status V3CS + 214 H2S Analyzer 1 Validity - 260 Valve 3 Close Status V3CS - 215 Valve 1 Open Command V1OC + 261 Misc Valve Open Status MVOS + 216 Valve 1 Open Command V1OC - 262 Misc Valve Open Status MVOS - 217 Valve 1 Close Command V1CC + 263 Misc Valve Close Status MVCS + 218 Valve 1 Close Command V1CC - 264 Misc Valve Close Status MVCS - 219 Valve 2 Open Command V2OC + 270 24 VDC + 220 Valve 2 Open Command V2OC - 271 24 VDC + 221 Valve 2 Close Command V2CC + 272 24 VDC + 222 Valve 2 Close Command V2CC - 273 24 VDC + 223 Valve 3 Open Command V3OC + 274 24 VDC + 224 Valve 3 Open Command V3OC - 275 24 VDC + 225 Valve 3 Close Command V3CC + 276 24 VDC + 226 Valve 3 Close Command V3CC - 277 24 VDC + 227 Misc Valve Open Command MVOC + 278 24 VDC Return - 228 Misc Valve Open Command MVOC - 279 24 VDC Return - 229 Misc Valve Close Command MVCC + 280 24 VDC Return - 230 Misc Valve Close Command MVCC - 281 24 VDC Return - 231 Remote Set 1 Raise Command RS1R + 282 24 VDC Return - 232 Remote Set 1 Raise Command RS1R - 283 24 VDC Return - 233 Remote Set 1 Lower Command RS1L + 284 24 VDC Return - 234 Remote Set 1 Lower Command RS1L - 235 Remote Set 2 Raise Command RS2R + 236 Remote Set 2 Raise Command RS2R - 237 Remote Set 2 Lower Command RS2L + 238 Remote Set 2 Lower Command RS2L - 239 Remote Set 3 Raise Command RS3R + 240 Remote Set 3 Raise Command RS3R - 241 Remote Set 3 Lower Command RS3L + 242 Remote Set 3 Lower Command RS3L - 243 Spare + 244 Spare - 245 Spare + 246 Spare -

Rev. No. 3.0


Stations

Spec. No. 52

Rev. Date 3/25/2013


MJB1 Continued

# Frequency Output Terminal Strip FTS1 # Frequency Output Terminal Strip FTS1 301 Meter 1 Frequency + 308 Meter 4 Frequency - 302 Meter 1 Frequency - 309 Meter 5 Frequency + 303 Meter 2 Frequency + 310 Meter 5 Frequency - 304 Meter 2 Frequency - 311 Meter 6 Frequency + 305 Meter 3 Frequency + 312 Meter 6 Frequency - 306 Meter 3 Frequency - 313 Meter Spare Frequency + 307 Meter 4 Frequency + 314 Meter Spare Frequency -

# Misc. Comm. Cables (Used for USM RS232/485)

401-406 3PR Belden #1592A + 1PR Spare 407-412 3PR Belden #1592A + 1PR Spare 413-418 3PR Belden #1592A + 1PR Spare 419-424 3PR Belden #1592A + 1PR Spare 425-430 3PR Belden #1592A + 1PR Spare

MJB2 AC only Jnct. Box located inside meter building. Each device listed to be on its own circuit breaker. All wiring from device to terminal to be labeled with the terminal number.

# AC Junction Box ACTS1 # AC Junction Box ACTS1 # AC Junction Box ACTS1 500 Lighting Interior Line 510 Oxygen Analyzer Line 520 Instrument Supply Heater Line 501 Neutral 511 Neutral 521 Neutral 502 Lighting Exterior Line 512 H2S Analyzer Line 522 Spare Line 503 Neutral 513 Neutral 523 Neutral 504 Heat Trace Tubing Line 514 Meter Building Receptacle(s) Line 524 Spare Line 505 Neutral 515 Neutral 525 Neutral 506 Heating Blanket Line 516 Gas Chromatograph Line 526 Spare Line 507 Neutral 517 Neutral 527 Neutral 508 Moisture Analyzer Line 518 A/C Heater Line 528 Spare Line 509 Neutral 519 Neutral 529 Neutral

Rev. No. 3.0


Stations

Spec. No. 52

Rev. Date 3/25/2013


16. Communication

16.1. Communication requirements for each facility must be reviewed and approved by Dominion Transmissions Communication Department.

16.2. This is a long lead item; proper provisions should be made as soon as practical.

16.3. There must be a 911 address assigned to the location before any communication company will start their process. This is the responsibility of the owner of the facility.

16.4. Communication between the facilitys Flow Computer and the SCADA System in Clarksburg, WV must be established and properly working prior to placing the facility into operation.

16.5. Backup communications shall be an unpublished dial up phone line unless otherwise approved by DTIs Communication Department.

17. Integrity & Corrosion

17.1. Pipeline Integrity and Corrosion requirements for each facility must be reviewed and approved by Dominion Transmissions Pipeline Integrity Department.

17.2. Integrity and Corrosion requirements include, but are not limited to:

17.2.1. Atmospheric Corrosion (Painting)

17.2.2. Cathodic Protection

17.2.3. Coatings (Below Grade)

17.2.4. DC Voltage Gradient Surveys

17.2.5. AC Attenuation Surveys

17.3. All cathodic protection systems shall be designed by a NACE-certified Cathodic Protection Specialist

17.4. All coating and painting application work shall be performed under the direct on-site supervision and control of a NACE-certified Coating Inspector Level 1 (NACE CIP 1) or equal to be approved in writing by Dominion Transmissions Pipeline Integrity Department.

17.5. All cathodic protection installation work and ac mitigation installation work shall be performed under the direct on-site supervision and control of a NACE Certified Cathodic Protection Technician (NACE CP2) of higher.


Stations

Spec. No. 52

Rev. No. 3.0 Rev. Date 3/25/2013


18. Standard Material Specification

18.1. Standard Material Specifications for Measurement and Regulation Facilities are determined by Dominion Transmissions Measurement Engineering and Support (ME&S) Department and are included in this document. Any deviation from the standards set forth in this document requires written approval from ME&S.

19. Standard Drawings

19.1. Standard Drawings for Measurement and Regulation Facilities may be provided, by request, by Dominion Transmissions Engineering Services or Measurement Engineering and Support (ME&S) Department and are included in this document. Any deviation from the standards drawings set forth in this document requires written approval from ME&S

20. Waivers & Variances

20.1. Any requested waivers or deviation from the standards set forth in this document requires written approval from Dominion Transmissions Measurement Engineering and Support (ME&S) Department.

20.2. Any changes or modifications to existing measurement facilities shall be submitted, in writing, for approval by ME&S prior to the start of any construction.

21. Appendices & Attachments

21.1. Approved Measurement Operating Equipment

21.2. Capacity Tables

21.3. Standard Drawings

a) ME&S Minimum Meter Design Requirements & Design Form b) Ultrasonic meter Procurement Drawings: DS-X1150 to DS-X1153 c) Orifice meter Procurement Drawings: DS-X1154 to DS-X1158 d) Turbine meter Procurement Drawings: DS-X1160 to DS-X1162 e) Coriolis meter Procurement Drawing: DS-X9758 f) Rotary meter Procurement Drawings: DS-W62A, DS-W62B, & DS-W62C g) Foundation Drawings: DS-X7446H & h) Grounding Drawings: DS-X7446J & DS-X7446K i) Sampling System Drawing: MST-PNY-11_6-12766 j) Manifold Drawings: Dominion 5, 7, AK-002-HD, and M-617XDT k) Fence Drawing: SF-Z3722A

Rev. No. 03

Equipment Specification

Spec. No. 52

Date 3/25/2013


Approved Measurement Operating Equipment Please note that equipment not shown or listed in the Equipment Specification section of this specification is unacceptable for installation in a Dominion Transmission, Inc. owned or operated facility. Any deviation from this list will require written approval from Dominions Measurement Engineering and Support (ME&S) Department.

All purchases and specification of Meters (Section 1) shall be reviewed and approved by DTIs Measurement Engineering and Support (ME&S) Group.

Table of Contents

MEASUREMENT 4

1.1. Ultrasonic Meter (USM) 41.1.1. Daniel SeniorSonic Gas Flow Meter. 41.1.2. Sick Maihak FLOWSIC600 Gas Flow Meter 41.2. Turbine Meters 41.2.1. Sensus Auto-Adjust II Turbo Meter 51.3. Orifice Meter 51.3.1. Daniel Fittings 51.3.2. TMCO Fittings 51.4. Coriolis Meter 61.4.1. Emerson Micromotion 61.6. Rotary Meter 71.6.2. Pulser 71.6.3. Barrier 71.7. Diaphragm Meters 71.7.1. American Meter 71.7.2. Pulser 71.7.3. Barrier 71.8. Flow Conditioners 71.8.1. CPA 50e 7

INSTRUMENTATION 8

1.9. Static Gauge Pressure Transmitter 81.9.1. Rosemount Model 3051CG-5-A-2-2-A-1-A-E5-B4-M5 81.9.2. Rosemount Model 3051CG-4-A-2-2-A-1-A-E5-B4-M5 81.10. Differential Pressure Transmitter 91.10.1. Rosemount Model 3051CD-2-A-2-2-A-1-A-E5-B4-M5 91.11. Temperature Transmitter 91.11.1. Rosemount Model 3144P-D1-A-1-E5-B4-M5 91.11.2. Rosemount Platinum RTD Model 0078-R-21-N-00-A-XXX-T22-E5 101.11.3. Rosemount Thermowell Model 0091-A-XXX-T22-T000-P-R23 10

Rev. No. 03


Spec. No. 52

Date 3/25/2013


1.12. Instrumentation Manifold System 101.12.1. PGI Direct Mount (for Daniel Ultrasonic Meters) 101.12.2. Remote Mount System (for Sick Ultrasonic Meters) 111.12.3. PGI Direct Mount (for Orifice Meters) 111.13. Gas Flow Computer (GFC) 111.13.1. Bristol Babcock Control Wave Micro 11

CONTROL 13

1.14. Operator/Actuator for Station Control 131.14.1. Shafer 131.15. Operator/Actuator for Run Switching 131.15.1. Shafer 131.16. Digital Valve Controllers 131.16.1. Fisher FIELDVUE DVC6200 131.17. Remote Set Regulators 131.17.1. Bristol Babcock 131.18. Pneumatic Valve Controller 131.18.1. Fisher Wizard 131.18.2. Pneumatic High-Pressure Select Relay 131.19. Instrument Supply System 131.19.1. Fisher 1367 Supply System 131.20. Relief Valves 141.20.1. Mercer 9500 Piloted Relief Valve 14

GASQUALITY 14

1.21. Gas Chromatograph 141.21.1. Daniel Danalyzer Model 570 Gas Chromatograph 141.21.2. Daniel Model 2350A Controller w/ Keypad 141.21.3. Helium Carrier Gas Regulator 151.21.4. Calibration Gas Regulator 151.21.5. Documentation: 151.22. Moisture Analyzers 151.22.1. SpectraSensors 151.22.2. General Electric (GE) 151.23. Oxygen Analyzers 151.23.1. SpectraSensors 151.23.2. Advanced Micro Instruments (AMI) 151.23.3. Calibration Gas Regulator 161.24. Hydrogen Sulfide Analyzers 161.24.1. SpectraSensors 161.25. Gas Sampling Equipment 161.25.1. Sampling Systems 161.25.2. Sample Probes 16

Rev. No. 03


Spec. No. 52

Date 3/25/2013


HEATERS 17

1.26. Catalytic Heaters (if required) 171.26.1. Bruest 17

MISCELLANEOUS 17

1.27. Miscellaneous Equipment 171.27.1. Combustible Gas Detectors (if required) 171.27.2. Fire / Flame Detectors (if required) 171.27.3. Charger & Batte

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