1. Saskatchewan Measurement Directive PNG017 DRAFT CHANGES
2/17/2019
Saskatchewan Measurement Directive PNG017 DRAFT CHANGES
Saskatchewan Measurement Directive PNG017 Introduction

2. Measurement Committee
Alison Dolter, Information Management
Scott Lenz, Field Services
Mathew Lix, Resource Management
Any questions please

3. Implementation Process
Draft Consultation starting late September
Approximate implementation date December 2018
Link to draft version will be found at

4. Proposed Changes Section 15.2.9 Brine Measurement and Reporting
Clarification
The product BRINE is only reported at licensed disposal wells and injection facilities related to the potash industry.
This section presents the requirements for measurement and reporting of brine injection into potash disposal wells and only applies to Saskatchewan.
All brine injected into potash disposal wells must be reported to Petrinex. Reported brine volumes must be corrected to 15°C.
Brine injected into disposal wells must be continuously metered at each wellhead at the injection site and used for reporting to Petrinex. Brine injected into disposal wells constructed prior to September 11, 2012 must be continuously metered into individual wells but may be metered at the injection facility or a field injection header if the meter is not located at the wellhead.
For general liquid measurement, liquid volume calculation, data verification, audit trail, and EFM requirements, see Section 14.
For brine meter proving method, see Sections 2.4 and 2.8.
See Sections 1.7 for uncertainty limits.

5. Proposed Changes – Section 2.5.1.1 Oil Meter Exemption
Current Point #2 b.
If the meter is used to measure test volumes of heavy oil or emulsion (density ≥ 920 kg/m3)
Clarification
Point #2 b.
If the meter is used to measure test volumes of heavy oil or emulsion (oil density ≥ 920 kg/m3)

6. Proposed Changes – Amendments
Current
Section Production Data Verification and Audit Trail
Clarification
Section Amendments Requirements for Reported Information in Petrinex
Section heading is changing to reflect what the section relates to. This section does not apply in Saskatchewan.

7. Proposed Changes – Audit Trail
Current
Section Production Data Verification and Audit Trail
Proposed
Section Data Verification and Audit Trail
Removing the word production since the data verification and audit trail applies to all data this submitted to Petrinex not just data related to production.

8. Proposed Changes – Section 4.2.8 Other Facilities Gas Measurement
Current
Provisions of this section apply where these facilities are required to measure and report gas. Gas must be measured as a single phase.
Clarification
These facilities are required to measure and report gas, if there is gas. Gas must be measured as a single phase.

9. Proposed Changes – Section 3.1 Proration/Allocation Factors
Current No reference to where to find how to determine the proration and allocation factors
Clarification
Examples of how to calculate and report the proration and allocation factors can be found in Directive PNG032 and Section 6.

10. Proposed Changes – Section 3.2 Metering Difference for Fluids
Clarification
Imbalance (Petrinex term for metering difference) is not allowed to be reported for products of Oil and Condensate.
For facilities using proration or allocation production accounting methodology, a metering difference is not allowed to be reported for all products.

11. Proposed Changes – Section 14.7.3 Manual Tank Gauging
Current
Calibration of gauge board is not required
Addition
Calibration of gauge board is not required, however verification of gauge boards is required on a yearly basis as per API MPMS Chapter 2.

12. Proposed Changes – Section 1.8.1 Measurement Schematics Requirements
Addition
Require operators to add to the measurement schematic
- Facility or well licence number of the facility
- Oil Satellites must be shown on the battery measurement schematic they are associated with and must include the facility ID, facility licence number and equipment.
- Compressors must be shown on the facility’s measurement schematic they are associated with and must include the facility ID, facility licence number, horsepower and energy source (gas, propane, electricity).
- Fuel, flare, or vent take-off points – write on the measurement schematic the word ‘Fuel’, ‘Flare’ or ‘Vent’ beside the take off point and if no meter is listed then shown ‘EST’ beside take-off point.
- Require Tank and vessel capacity must be shown on measurement schematic.

13. Proposed Changes Section 1.1 Introduction
Current
The specific standards of accuracy are listed in Section 1.7. If an inspection of a measurement device or of procedure reveals unsatisfactory conditions that significantly reduces measurement accuracy, the Regulator will direct that the licensee implement changes to improve measurement accuracy, and this direction will become a condition of operation for the facility or facilities.
Addition
The specific standards of accuracy are listed in Section 1.7. Operators must inspect the site to ensure the measurement equipment is in good working order. If an inspection of a measurement device or of procedure reveals unsatisfactory conditions that significantly reduces measurement accuracy, the Regulator will direct that the licensee implement changes to improve measurement accuracy, and this direction will become a condition of operation for the facility or facilities.

14. Proposed Changes - Fuel, Flare and Vent Definitions
Fuel Gas: Gas that is combusted and the released energy is used in upstream oil and gas operations.
Examples of gas usage scenarios that must be reported as fuel gas include the following:
engines
catalytic heaters and other building heaters
process vessel burners
sulphur recovery unit reaction furnaces
line heaters
thermal electric generators (TEGs)

15. Proposed Changes - Fuel, Flare and Vent Definitions
Flare Gas: Gas that is combusted in a flare or incinerator at upstream oil and gas operations.
Examples of gas usage scenarios that must be reported as flare gas include the following:
waste gas
pilot gas
dilution and make-up gas added to a flare gas stream before flaring or incineration
acid gas (routine and non-routine)upset)
blanket gas, purge gas, and sweep gas
gas used to operate pneumatic devices (instruments, pumps, and compressor starters)
gas from dehydrator still columns
gas produced during well completions gas
gas produced during well unloading operations volumes
equipment failures or plant upsets that result in gas being flared or incinerate

16. Proposed Changes - Fuel, Flare and Vent Definitions
Vent Gas: Uncombusted gas that is intentionally or unintentionally released to the atmosphere at upstream oil and gas operations.
Examples of gas usage scenarios that must be reported as vent gas include the following:
waste gas
gas used to operate pneumatic devices (instruments, pumps, compressors starters, and compressor blow down etc.)
equipment failures or plant upsets that result in gas being released to the atmosphere
gas from dehydrator still columns
production tank vapor (e.g., condensate, oil). Methanol and chemical tanks not included.
gas vented during pigging operations.
gas produced during well completions gas produced during well unloading operations
blanket gas

17. Proposed Changes – Section 4
Proposed Changes – Section 4.2 Gas Measurement and Accounting Requirements for Various Facility Subtypes
Current No current requirement
Addition
As of January 1, 2019, Operators must report FUEL, FLARE and VENT volumes based on the new definitions listed in version 3 of Directive PNG017.

18. Proposed Changes Section 1.6.3.5 Gas Systems – Fuel Gas
Current
No current requirements
Addition
For facilities licenced or for non licenced facilities built before April 1, 2020, the volume of gas vented by pneumatic devices that is reported as vented may be estimated and then subtracted from the metered fuel gas volume in the case where the metered fuel gas provides the pneumatic gas supply.
For facilities licenced or for non licenced facilities built before April 1, 2020, the volume of flared gas used as pilot, purge and makeup gas may be estimated and then subtracted from metered fuel gas in the case where metered fuel gas also provides the pilot, purge and makeup gas supply.
For facilities licenced or for non licenced facilities built before April 1, 2020, pilot, purge and makeup gas that is flared may be estimated in addition to the m3/d that may be estimated for flare gas.

19. Proposed Changes Section 1.6.3.6 Gas Systems – Flare and Vent Gas
Current
No current requirements
Addition
For facilities licenced or for non licenced facilities built before April 1, 2020, the volume of flare gas used as pilot, purge and makeup gas may be estimated and then subtracted from metered fuel gas in the case where metered fuel gas also provides the pilot, purge and makeup gas supply.
For facilities licenced or for non licenced facilities built before April 1, 2020, the purge, pilot and makeup gas that is flared may be estimated in addition to the m3/d that may be estimated for flare gas.
Uncombusted gas released to the atmosphere that is not fugitive emissions must be reported as vent gas (see the glossary definition of vent gas). Saskatchewan specifies vent gas limits for sites.

20. Proposed Changes Section 4. 2. 1 Oil Batteries & Section 4. 2
Proposed Changes Section Oil Batteries & Section Gas Batteries
Current
No current requirements
Addition
Point 4
Any oil facility such as well sites, batteries, and oil satellites operators may estimate fuel gas use volumes for sites with an annual average fuel gas use of m3/d or less. This requirement to measure meter the fuel gas exceeding m3/d applies. The m3/d measurement limit for fuel gas also applies to flare and vent gas volumes, excluding heavy crude oil. At sites where fuel gas metering is required, up to m3/d may be estimated.

21. Proposed Changes Section 4. 2. 1 Oil Batteries & Section 4. 2
Proposed Changes Section Oil Batteries & Section Gas Batteries
Current
No current requirements
Addition
For facilities licensed or for non-licensed facilities built before April 1, 2020, the volume of gas vented by pneumatic devices that is reported as vented may be estimated and then subtracted from the metered fuel gas volume in the case where the metered fuel gas provides the pneumatic gas supply.

22. Proposed Changes Section 1 Gas Systems – Fuel Gas & Flare Section 4. 2
Proposed Changes Section 1 Gas Systems – Fuel Gas & Flare Section Oil Batteries & Section Gas Batteries
Current
No current requirements
Addition
For facilities licenced or for non licenced facilities built before April 1, 2020, the volume of flare gas used as pilot, purge and makeup gas may be estimated and then subtracted from metered fuel gas in the case where metered fuel gas also provides the pilot, purge and makeup gas supply.

23. Proposed Changes Section 1 Gas Systems – Flare Gas Section 4. 2
Proposed Changes Section 1 Gas Systems – Flare Gas Section Oil Batteries & Section Gas Batteries
Current
No current requirements
Addition
For facilities licenced or for non licenced facilities built before April 1, 2020, the purge, pilot and makeup gas that is flared may be estimated in addition to the m3/d that may be estimated for flare gas.

24. No gas analysis requirements for vented gas Addition
Proposed Changes – Section Crude Oil Single Well Battery and Crude Oil Multiwell Group Battery
Current
No gas analysis requirements for vented gas
Addition
Add the gas analysis requirement that for vented gas at a single well battery a initial representative analysis is required.

25. Proposed Changes – Section 8.4 Sampling and Analysis Frequency
Current
New gas and condensate samples must be taken for all new wells and measurement points within 30 days following the first month of production. For the time period prior to receipt of a new composition, a substitute composition may be used for gas measurement and gas equivalent of liquid calculations.
Addition
New gas and condensate samples must be taken for measurement points within 30 days after the on production date. For the time period prior to receipt of a new composition, a substitute composition may be used for gas measurement and gas equivalent of liquid calculations.

26. Proposed Changes – Section 8.4 Sampling and Analysis Frequency
Current
No requirement for well completion gas analysis
Addition
For all new oil and gas well completions a gas sample must be taken at the wellhead (including casing gas) and gas analysis conducted within 30 days of the on production date and must be submitted as per Minister’s specifications listed in Directive PNG013: Well Data Submission Requirements.

27. Proposed Changes – Section 8.4 Sampling and Analysis Frequency
Current
No requirement for resubmission of well completion gas analysis.
Addition
For every oil and gas well completion a gas sample must be taken at the wellhead (including casing gas) and gas analysis conducted every ten years for only active well completions based on the test date and must be submitted as per Minister’s specifications listed in Directive PNG013: Well Data Submission Requirements.

28. Implementation Process
Draft Consultation starting late September
Approximate implementation date December 2018
Link to draft version will be found at

29. Questions?