Gas Industry Standards Update

1
Gas Industry Standards Update

• Ed Bowles Dr. Darin George
• Southwest Research Institute
• SGA Operating Conference
• Transmission Measurement Roundtable
• July 18-20, 2006

2
AGA Report No.5 - Measurement of Natural Gas
Energy by Direct, Indirect, and Inferential
Methods

• Introduction to Gas Energy Measurement
• Terminology
• Operating Conditions
• Energy Meter Requirements
• Performance Requirements
• Individual Meter Testing Requirements
• Installation Requirements
• Field Verification Tests
• References
• Appendix Energy Measurements for Natural Gas
  Applications

Note Items shown in red are undergoing
significant revision.
3
Revision of AGA Report No.5

• Essentially a complete re-write of the
  recommended practice.
• Will address calorimetry, titration, and
  correlative methods of determining natural gas
  energy content.
• The document update is expected to be completed
  in 2006 (possibly) or 2007 (probably).

4
AGA Report No.7 - Measurement of Natural Gas by
Turbine Meters

• Meter Maintenance Field Verification Checks
• Appendices
• Turbine Meter Designs
• Volumetric Mass Flow Measurement
• Computing Flow
• Calibration Guidelines
• References

• Introduction
• Terminology
• Operating Conditions
• Meter Design Requirements
• Performance Requirements
• Individual Meter Testing Requirements
• Installation Specifications

Note Items shown in red have undergone
significant revision.
5
Revisions to AGA Report No.7

• Last issued in 1996. The revised version is now
  out.
• The document reflects recent changes in meter
  technology with the introduction of dual-rotor
  meters and extended capacity meters.
• The document is now a performance-based standard
  that places minimum requirements on meter
  performance.

6
Revisions to AGA Report No.7 (continued)

• Revisions include
• An updated discussion of calibration quantities,
  including K factors, meter factors and rotor
  factors for dual-rotor meters.
• General performance tolerances for meters at
  atmospheric pressure, and expectations for
  performance at elevated pressures.
• Requirements for internal flow conditioning.
• New requirements for documenting meter
  performance.

7
Revisions to AGA Report No.7 (continued)

• Additional revisions
• Expected shifts in meter performance due to
  changes in gas density and cartridge change-out
  practices.
• Appendices
• Common meter designs.
• Examples of mechanical and electronic adjustments
  to meter output.
• Guidelines for selecting calibration conditions
  that represent expected field conditions
  (Reynolds number and density matching).

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AGA Report No.9 - Measurement of Gas by Multipath
Ultrasonic Meters

• Introduction
• Terminology, Definitions, Units
• Operating Conditions
• Meter Requirements
• Performance Requirements
• Individual Meter Testing Requirements
• Installation Requirements
• Field Verification Tests
• Ultrasonic Meter Measurement Uncertainty
  Determination
• Reference List
• Appendix A - Multipath Ultrasonic Flow Meter
  Calibration Units
• Appendix B - Electronic Design Testing
• Appendix C - Engineering Technical Note
• Appendix D - Flow Meter and/or Flow Conditioner
  Performance Verification Test
• Appendix E - Example of Measurement Uncertainty
  Calculation

Note Items shown in red are undergoing
significant revision.
9
Revisions to AGA Report No.9

• New elements
• Section 3 - Added discussion of acoustic noise
  interference
• Section 4 - Revised discussion pertaining to
  meter body lengths and bores and added discussion
  about electronic component replacement
• Section 5 - Flow calibration required for custody
  transfer applications
• Section 6 - Expanded discussion of flow
  calibration test
• Section 7 - Addition of default piping
  installation configuration
• Section 9 - Added discussion of measurement
  uncertainty determination

10
Ultrasonic Meter Performance Specifications(Uncha
nged)
11
Recommended Default Unidirectional and
Bi-directional Installations
12
Revisions to AGA Report No.9(continued)

• The re-write of the document is complete and has
  been balloted and approved by the AGA
  Transmission Measurement Committee.
• Release of the revised report is imminent.
• Check with the American Gas Association for the
  release date.

13
API MPMS Chapter 22.2 - Testing Protocol for
Differential Pressure Flow Measurement Devices

• Introduction
• Terminology Definitions
• Required Tests
• Installation Test Facility Requirements
• Flow Rate Equation
• Procedure for Reporting Meter Performance Results
• Appendix Test Matrix

Note Items shown in red have undergone
significant revision.
14
Revisions to API MPMS Chapter 22.2

• First issued in 2003.
• A revised edition was issued in 2005.
• Revisions included
• Discussions of geometric similarity and meter
  asymmetry effects.
• Changes to the procedure for qualifying the flow
  facility.
• An increase in the base number of test points
  (Reynolds numbers) from five to ten.

15
Revisions to API MPMS Chapter 22.2(continued)

• Additional revisions
• New requirements for tests with close downstream
  disturbances and special installations.
• Requirements for expansibility factors used in
  tests.
• Expanded reporting requirements.
• Expanded requirements for reporting uncertainty
  calculations.

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API MPMS Chapter 14.3, Part 1 General Equations
and Uncertainty Guidelines Concentric,
Square-Edged Orifice Meters

• The expansion factor coefficient correlation
  referenced in API MPMS, Chapter 14.3, Part 1
  (i.e., the Buckingham equation) is different than
  one recently adopted by the International
  Standards Organization for their orifice meter
  standard.
• The differences between the two are only
  significant in instances in which the
  differential pressure is high and the line
  pressure is low.

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Addendum to API MPMS Chapter 14.3, Part 1

• Additional tests have been run at SwRI and the
  Colorado Engineering Experiment Station to
  compare the two correlations.
• The API will be issuing an addendum to Chapter
  14.3, Part 1 to address this issue.
• Check with the American Petroleum Institute for
  the status of the pending addendum.

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API MPMS Chapter 14.1 - Collecting and Handling
of Natural Gas Samples for Custody Transfer

• Safety, Labeling, Handling, and Transportation of
  Cylinders
• Guidelines for Laboratory Analysis
• References
• Addendum on Auto-ignition
• Appendix A Phase Diagram
• Appendix B Fluid Mechanical Considerations in
  Gas Sampling
• Appendix C Lessons Learned During Sampling in
  Hydrocarbon Saturated and Two-Phase Natural Gas
  Streams
• Appendix D Hydrogen Sulfide Warning
• Appendix E API Laboratory Inspection Checklist
• Appendix F New Sampling Method Verification
  Procedure

• Introduction
• Purpose Scope
• Referenced Publications
• Definitions
• Hydrocarbon Dew Point
• General Considerations for Sample System Design
• Sample Probes
• Sample Loops/Lines
• Sample Containers
• Materials for Sweet Sour Gas Service
• Other Apparatus
• Spot Sampling Methods
• Automatic Sampling
• Sampling Intervals

Note Items shown in red have undergone
significant revision.
19
Revisions to API MPMS Chapter 14.1

• A revision of API MPMS Chapter 14.1 was issued
  earlier this year.
• Section 7 - Sampling Probe
• Addresses potential of failure via probe
  vibration.
• Language to clarify the location of sample probes
  downstream of flow obstructions.
• Section 12 Spot Sampling Methods
• Will allow the substitution of various valves for
  the drilled plug required by GPA 2166-04 in the
  fill-and-empty method. Substitution requires
  that the pressure drop and Joule-Thomson cooling
  must occur at the end of the pigtail.

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Revisions to API MPMS Chapter 14.1(continued)

• Section 16 - Calibration Gas Blends
• Requirements for preparation and statements of
  composition accuracy.
• Sampling Verification Test Protocol (Appendix F)
• A protocol for evaluating new natural gas
  sampling methods and documenting results.
• Addendum on Auto-ignition

21
GPA 2166 Obtaining Natural Gas Samples for
Analysis by Gas Chromatography

• The new revision (2005) contains major changes
  from the previous version (1986).
• Changes include
• Emphasis on knowledge of the phase behavior and
  hydrocarbon dew point of the gas being sampled,
  and related equipment heating requirements.
• Clarification of the proper use of the gas
  sampling separator.
• Recommended equipment list for each sampling
  procedure.

22
GPA 2166 Obtaining Natural Gas Samples for
Analysis by Gas Chromatography

• Scope
• Notes
• List of Sampling Methods
• General Information
• Hydrocarbon Dew Point
• Guide for the Selection of a Proper Sampling
  Procedure
• Apparatus
• Heating Requirements
• Sampling Procedures for Spot Samples

• Handling of Sample Containers in the Laboratory
• Safety
• Appendix A Cleaning
• Appendix B Separators and Membrane Filters
• Appendix C Portable Gas Chromatograph
  Considerations
• Appendix D Sampling Systems for On-Line
  Analyzers

Note Items shown in red have undergone
significant revision.
23
Revisions to GPA 2166(continued)

• Guidelines for maximum probe lengths.
• Safety notes.
• New appendices give guidelines for
• Equipment cleaning.
• The use of separators and filters.
• The use of gas chromatographs.
• Changes to this standard have been made to
  harmonize it with API MPMS Chapter 14.1.

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Revisions to GPA 2166(continued)

• For the fill-and-empty sampling method, API MPMS
  Chapter 14.1 and GPA 2166 have relaxed the
  requirement for a drilled plug on the pigtail and
  allow for other flow restrictions, such as a
  multi-turn needle valve, that meet specific
  requirements.