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PART 1Onshore Upstream Oil and Gas Facilities (continued)

General Requirements (continued)

Compressors (continued)

Marginal note:Continuous monitoring devices

 A continuous monitoring device must

  • (a) be calibrated in accordance with the recommendations of the manufacturer of the device such that its measurements have a maximum margin of error of ±10%;

  • (b) be operated continuously, other than during periods when it is undergoing normal servicing or timely repairs; and

  • (c) be equipped with an alarm that is triggered when the applicable flow rate limit referred to in subsection 18(2) or (3) for the vents of the compressor is reached.

Marginal note:Corrective action

  •  (1) If the flow rate of emissions of hydrocarbon gas released from vents referred to in paragraph 14(b) of a compressor, measured in accordance with subsection 16(2), is greater than the applicable flow rate limit set out in subsection (2) or (3) or if the alarm referred to in paragraph 17(c) is triggered, corrective action must be taken to reduce that flow rate to below or equal to that limit, as demonstrated by a remeasurement that results,

    • (a) when a flow meter is used for the remeasurement, in a reading that is below or equal to that limit; or

    • (b) when a continuous monitoring device is used for the remeasurement, in the absence of an alarm when the compressor resumes operation following the taking of the corrective action.

  • Marginal note:Flow rate limit — centrifugal compressors

    (2) For emissions that are from the seals of a centrifugal compressor, the flow rate limit is

    • (a) if the compressor is installed on or after January 1, 2023, 0.14 standard m3/min; and

    • (b) if the compressor is installed before January 1, 2023 and has a rated brake power of

      • (i) greater than or equal to 5 MW, 0.68 standard m3/min, and

      • (ii) less than 5 MW, 0.34 standard m3/min.

  • Marginal note:Flow rate limit — reciprocating compressors

    (3) For emissions that are from the rod packings and distance pieces of a reciprocating compressor, the flow rate limit is

    • (a) if the compressor is installed on or after January 1, 2023, the product of 0.001 standard m3/min and the number of pressurized cylinders that the compressor has; and

    • (b) if the compressor is installed before January 1, 2023, the product of 0.023 standard m3/min and the number of those pressurized cylinders.

  • Marginal note:Remeasurement

    (4) The remeasurement referred to in paragraph (1)(a) or (b) must be taken in accordance with section 15 on or before the later of

    • (a) the 90th day after the day on which, as the case may be, the most recent measurement is taken under subsection 16(3) or the alarm referred to in paragraph 17(c) is triggered, and

    • (b) if the estimated volume of hydrocarbon gas, expressed in standard m3, that would, beginning from the day on which the applicable day described in paragraph (a), be emitted until that next planned shutdown if no corrective action were taken is equal to or less than the volume of hydrocarbon gas, expressed in standard m3, that would be emitted due to the purging of hydrocarbon gas in order to take the corrective action,

      • (i) the day on which the compressor begins to operate after the next planned shutdown, in the case of a centrifugal compressor, and

      • (ii) the day on which the compressor is first pressurized after the next planned shutdown, in the case of a reciprocating compressor.

  • Marginal note:Estimated volume

    (5) The estimated volume of hydrocarbon gas must be based on the most recent flow rate of emissions of hydrocarbon gas released from vents referred to in paragraph 14(b) of the compressor, as determined by a flow meter or a continuous monitoring system in accordance with section 15.

Marginal note:Records — compressors and vents

  •  (1) A record must be made that indicates for each compressor referred to in section 14

    • (a) its serial number;

    • (b) its make and model;

    • (c) its rated brake power;

    • (d) the date on which it was installed at the facility, if it was installed on or after January 1, 2020, or a demonstration, with supporting documents, that it was installed at the facility before January 1, 2020;

    • (e) if applicable, the type of hydrocarbon gas conservation equipment or hydrocarbon gas destruction equipment to which the emissions of hydrocarbon gas from the its seals or rod packing and distance pieces, as the case may be, are captured and routed, namely

      • (i) a vapour recovery unit,

      • (ii) a vent gas capture system,

      • (iii) a flare,

      • (iv) an enclosed combustor, or

      • (v) another type, and if so, a description of the type;

    • (f) for each centrifugal compressor for which emissions from its seals are routed to vents that release those emissions to the atmosphere, whether the seals are dry or wet;

    • (g) for each reciprocating compressor from which emissions from its rod packings and distance pieces are routed to vents that release those emissions to the atmosphere, the number of those rod packings; and

    • (h) for each compressor for which the period within which a measurement by a flow meter must be made has been extended under subsection 16(6), the number of hours during which it was pressurized during the three calendar years referred to in that subsection.

  • Marginal note:Records — flow meters

    (2) A record must be made that indicates, for each measurement, including a remeasurement, the flow rate of emissions from a vent referred to in paragraph 14(b) made by means of a flow meter referred to in paragraph 15(a),

    • (a) the make and model of the flow meter;

    • (b) the maximum flow rate referred to in paragraph 16(4)(a) or the average flow rate referred to in paragraph 16(4)(b), as the case may be;

    • (c) the date on which the measurement was taken;

    • (d) the recommendations of the manufacturer for the calibration of the flow meter referred to in subsection 16(1), along with a demonstration, with supporting documents, that the measurements taken with that calibration have a maximum margin of error of ±10%;

    • (e) any recommendation for the taking of the measurement, along with supporting documents;

    • (f) the duration of the continuous period referred to in paragraph 16(4)(a) or (b), as the case may be; and

    • (g) the name of the person who took the measurement and, if that person is a corporation, the name of the individual who took it.

  • Marginal note:Records — continuous monitoring devices

    (3) A record must be made that indicates, for each measurement, including a remeasurement, of the flow rate of emissions from a vent referred to in paragraph 14(b) made by means of a continuous monitoring device referred to in paragraph 15(b),

    • (a) a description of the device;

    • (b) if applicable, its serial number, make and model; and

    • (c) the recommendations of the manufacturer for the calibration of the continuous monitoring device referred to in paragraph 17(a) along with a demonstration, with supporting documents, that the measurements taken with that calibration have a maximum margin of error of ±10%.

  • Marginal note:Records — corrective actions taken

    (4) A record must be made that indicates, for each corrective action taken,

    • (a) a description of the corrective action, including a description of each step of the corrective action;

    • (b) the dates on which that corrective action was taken, along with the dates on which each of its steps was taken;

    • (c) for each remeasurement taken under paragraph 18(4)(b), the volume and estimated volume, determined for the purpose of that paragraph, along with supporting calculations; and

    • (d) if the corrective action was taken as a result of a measurement by means of a continuous monitoring device, the date on which the alarm was triggered.

Conditional Requirements

Conditions

Marginal note:Application of sections 26 to 45

  •  (1) Sections 26 to 45 apply in respect of an upstream oil and gas facility as of the first day of the month that begins after the facility produces or receives — or is expected to produce or receive — a combined volume of more than 60 000 standard m3 of hydrocarbon gas for a period of 12 months, determined as follows:

    • (a) if the facility has operated during at least 12 months, whether consecutive or not, with at least one day of operation in each of those months, the combined volume of hydrocarbon gas, expressed in standard m3, produced or received based on records, for the most recent 12 of those months of operation;

    • (b) if the facility has operated during at least one month and less than 12 months, whether consecutive or not, with at least one day of operation in each of those months, the combined volume of hydrocarbon gas, expressed in standard m3, that the facility is expected to produce or receive for a 12-month period determined by prorating the combined volume, based on records, produced or received during those months of operation; and

    • (c) in any other case, the combined volume of hydrocarbon gas, expressed in standard m3, that the facility is expected to produce or receive during the 12-month period that begins after its first month of operation, as determined in accordance with the applicable method set out in section 23.

  • Marginal note:Well completion

    (2) For the purpose of subsection (1), if a well at the facility undergoes well completion during a given month, the portion of the combined volume referred to in that subsection that corresponds to the production of hydrocarbon gas from the well must be based on the volume of hydrocarbon gas expected to be produced by the well for the 12-month period after the given month, as determined in accordance with the applicable method set out in section 23.

 
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