Bulletin 2012-19

Bulletin 2012-19: Revised Edition of Directive 017: Measurement Requirements for Oil and Gas Operations Issued

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Revised Edition of Directive 017: Measurement Requirements for Oil and Gas Operations Issued

Sep 11, 2012

This bulletin announces the release of the revised edition of Energy Resources Conservation Board (ERCB) Directive 017: Measurement Requirements for Oil and Gas Operations, which replaces the edition issued on April 18, 2011, and is effective immediately. In the September 2012 edition, Sections 1.9, 1.10, and 4.3.3.2 (described below) as well as Appendices 9 and 10, are new; Section 7.4 has been extensively revised; and clarifications to the pre-existing 15 sections of Directive 017 have been made.

Due to the complexity of consolidating and clarifying existing requirements and updating them to take into account the current technological and operating environments, this directive is being developed in stages, with new sections added as they become available. Feedback on draft additions and revisions to Directive 017 released for review on January 31, 2012, were considered in finalizing the September 2012 edition of the directive.

The revised edition of Directive 017, as well as a summary of the feedback received on the drafts and the ERCB’s responses, is available on the ERCB website at www.ercb.ca. Printed copies of the directive may be purchased from ERCB Information Services, Suite 1000, 250 – 5 Street SW; telephone: 403-297-8311 or 1-855-297-8311 (toll free); fax: 403-297-7040; e-mail: infoservices@ercb.ca.

In the version available on the ERCB website, all changes made in editions published from 2007 to October 2011 appear in red type and all changes made since the previous edition (April 2011) appear in blue type.

Clarifications, Updates, and New Requirements in Sections 1 to 15

  • Section 1.2: Removed last paragraph.
  • Section 1.7.2(vi): Added “vent.”
  • Section 2.5.2.1: Added “structural integrity of” the primary measurement element.
  • Section 2.6, Table 2.1: Added the word “or” before delivery points and “emulsion” in Note 4.
  • Sections 2.6.1: Added in the first bullet “or the meter qualifies for bench proving or the meter must qualify for bench proving or be a Coriolis- type meter with sufficient structural integrity internal diagnostics” and “If there is a dump valve as part of the Coriolis or bench-proved measurement system, the dump valve must be checked for leaks at the same inspection or proving frequency set out in Table 2.1.” Added in the fourth bullet “the structural integrity of” the primary measurement element.
  • Section 3.2.1: Added “except for subtype 321 and 341 batteries” under Batteries.
  • Section 4.2.1.2: Removed “365.”
  • Section 4.2.2.2: Added in gas group delineation scenarios.
  • Section 4.2.2.4: Added in coalbed methane battery delineation scenarios.
  • Section 4.2.2.6: Added in oil battery delivering to or receiving from a gas plant delineation scenario.
  • Section 4.3.1, first paragraph: Added “or as approved by Measurement Canada.”
  • Section 4.3.1, item 7: Added “External gas sample analysis and density must be used to determine the gas volume at base conditions (see Section 4.3.2)” and removed “The installation must include instrumentation that allows for continuous temperature correction.”
  • Section 4.3.3.1, item 10: Removed “dilution” and added “The only exception is for integrated OWMF with WP, CT, and IF facilities on the same site, in which case fuel REC is to be reported at the ABWP and total OWMF fuel use at the same facility.”
  • Section 4.3.4.1: Added in the fifth bullet “The exception is for clean dry sales specification gas with minimal moisture, which is acceptable not to winterize.”
  • Section 5.4.1: Changed Initial Qualifying Criteria item 9 from 5.0 to 30.0 m3/month of net water production.
  • Section 5.5.1: Added in measurement-by-difference scenarios for measured gas into a proration battery.
  • Section 5.5.2, item 4: Added “prorated.”
  • Section 5.5.3.1, item 2: Added in the second bullet “if there is any Freehold objection.”
  • Section 5.7: Removed previous contents and inserted a reference to Section 7.4.
  • Section 6.2.2.4: Added in conditions for oil/emulsion double proration.
  • Section 6.4.3: Added that water-cut sample and analysis must be conducted for each test.
  • Section 7.4: Replaced most of this section with a newly revised version.
  • Section 8.2.1: Added “sample point” to title and first paragraph.
  • Sections 8.4, Table 8.3: Added water source gas sampling requirements.
  • Section 10.2: Added facility delineation scenarios.
  • Section 12: Removed numbered Introduction heading and renumbered the remaining headings accordingly.
  • Section 12.1.1: Under Exception, changed 0.08 to 0.07 per cent per degree Celsius.
  • Section 12.3.4: Added in other means for steam meter inspection.
  • Section 12.3.6: Added in exception for secondary measurement.
  • Section 14.4, Table 14.3: Added “or composite meter factor (see Section 14.9).”
  • Section 15.2.4: Added in wellhead meter must be used for reporting and water injection measurement scenarios.
  • Appendix 1: Removed all items under development that have been completed.

New Sections

  • Section 1.9: Measurement Schematics – This section presents the requirements and exceptions for measurement schematics used for measurement, accounting, and reporting of oil and gas facilities.
  • Section 1.10: Facility Delineation Requirements – This section presents the guidelines for delineating lease sites and geographic areas into reporting facilities. It is based on the measurement, accounting, and reporting requirements described in this directive and Directive 007.
  • Section 4.3.3.2: Gas Lift Systems for Both Oil and Gas Wells – This section presents the requirements for four gas source scenarios for lift gas, and each one may be subjected to different measurement, reporting, and sampling and analysis requirements when gas is injected into the wellbore to assist in lifting the liquids to the surface.
  • Appendix 9: Schematic example and Appendix 10: Gas group delineation scenarios are also new, as mentioned above.

Further Information

Please forward comments and questions to Bill Cheung, of the Field Surveillance and Operations Branch, by phone at 403-297-8798 or by e-mail at bill.cheung@ercb.ca.

<original signed by>

Robin King
Executive Manager
Field Surveillance and Operations Branch