GreatNorthCollective/greatnorth-canada-federal-laws-text huggingface dataset:
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 8
Records — conserved gas used as fuel 8 A record in respect of any hydrocarbon gas that is combusted as fuel in a combustion device referred to in paragraph 7 (a) must be made that indicates for each month during which the device is used, the percentage, at any given moment, of the combusted hydrocarbon gas that is released as hydrocarbon gas, with supporting documents, based on (a) tests conducted when the device operates under conditions recommended by the manufacturer for determining this percentage; or (b) measurements taken when the device operates under those conditions.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 9
Hydrocarbon gas destruction equipment 9 Hydrocarbon gas destruction equipment that is used at an upstream oil and gas facility must satisfy the requirements related to the destruction of hydrocarbon gas set out in (a) Sections 3.6 and 7 of Version 4.5 of the guideline entitled Flaring and Venting Reduction Guideline , published by the Oil and Gas Commission of British Columbia in June 2016, if the facility is located in British Columbia; (b) section 3 of the directive entitled Directive S-20: Saskatchewan Upstream Flaring and Incineration Requirements , published by the Government of Saskatchewan on November 1, 2015, if the facility is located in Manitoba or Saskatchewan; and (c) sections 3.6 and 7 of the directive entitled Directive 060: Upstream Petroleum Industry Flaring, Incinerating, and Venting , published by the Alberta Energy Regulator on March 22, 2016, in any other case.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 10
Records — hydrocarbon gas destruction equipment 10 A record in respect of any hydrocarbon gas destruction equipment used at an upstream oil and gas facility must be made that demonstrates, with supporting documents, that the requirements related to the destruction of hydrocarbon gas set out in the applicable document referred to in section 9 are satisfied.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 11
Application 11 (1) This section applies in respect of an upstream oil and gas facility that includes a well that undergoes hydraulic fracturing and whose production has a gas-to-oil ratio of at least 53:1, based on the most recent determination of the gas-to-oil ratio prior to the hydraulic fracturing. No venting (2) Hydrocarbon gas associated with flowback at a well at an upstream oil and gas facility must not be vented during flowback but must instead be captured and routed to hydrocarbon gas conservation equipment or hydrocarbon gas destruction equipment. Exception (3) Subsection (2) does not apply if all the gas associated with flowback at the well does not have sufficient heating value to sustain combustion.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 12
Records — hydraulic fracturing 12 A record in respect of each well at an upstream oil and gas facility that undergoes hydraulic fracturing must be made (a) that indicates the gas-to-oil ratio, based on the most recent determination of the gas-to-oil ratio prior to the hydraulic fracturing; (b) if that gas-to-oil ratio is at least 53:1, that demonstrates, with supporting documents, that the hydrocarbon gas associated with flowback was captured and routed to hydrocarbon gas conservation equipment or hydrocarbon gas destruction equipment; and (c) if hydrocarbon gas associated with flowback at the well is vented, the heating value of that gas.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 13
Non-application — British Columbia and Alberta 13 Sections 11 and 12 do not apply in respect of an upstream oil and gas facility that is located in (a) British Columbia, if the facility is subject to the requirements with respect to well completion involving hydraulic fracturing that are set out in the guideline entitled Flaring and Venting Reduction Guideline , published by the Oil and Gas Commission of British Columbia in June 2016; and (b) Alberta, if the facility is subject to the requirements with respect to well completion involving hydraulic fracturing that are set out in the directive entitled Directive 060: Upstream Petroleum Industry Flaring, Incinerating, and Venting , published by the Alberta Energy Regulator on March 22, 2016.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 14
Capture or venting of emissions 14 The emissions of hydrocarbon gas from the seals of a centrifugal compressor, or from the rod packings and distance pieces of a reciprocating compressor, that has a rated brake power of 75 kW or more at an upstream oil and gas facility must be (a) captured and routed to hydrocarbon gas conservation equipment or hydrocarbon gas destruction equipment; or (b) routed to vents that release those emissions to the atmosphere.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 15
Measurement of flow rate 15 The flow rate of emissions of hydrocarbon gas released from the vents referred to in paragraph 14 (b) of a compressor must be measured by means of (a) a flow meter, other than a calibrated bag, in accordance with section 16 ; or (b) a continuous monitoring device in accordance with section 17 .
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 16
Flow meters 16 (1) The flow meter must be calibrated in accordance with the manufacturer’s recommendations such that its measurements have a maximum margin of error of ±10%. Measurements by flow meters (2) Those measurements must be made (a) in accordance with the recommendations set out in the manufacturer’s manual, if any; (b) in the case of a measurement made without the use of negative pressure or a vacuum, while there is a tight seal over the vent; (c) in the case of a measurement on a centrifugal compressor, when the compressor is operating under conditions that are representative of the conditions during the previous seven days; and (d) in the case of a measurement on a reciprocating compressor, when the compressor is pressurized. Initial and subsequent measurements (3) The flow rate must be measured within the following periods: (a) initially, the period that ends on (i) January 1, 2021, if the compressor is installed at the facility before January 1, 2020, and (ii) the 365th day after the day on which the compressor was installed at the facility, in any other case; and (b) subsequently, the period that ends on the 365th day after the day on which a previous measurement was taken. Measurements — maximum or average (4) The initial and each subsequent measurement of the flow rate must be based on measurements made by the flow meter over a continuous period of at least five minutes and is (a) the maximum of the flow rates measured, if the measurements are made over a continuous period of at least five minutes and less than 15 minutes; or (b) the average of the flow rates measured, if the measurements are made over a continuous period of at least 15 minutes. Extension — not operating or not pressurized (5) Despite subsection (3), if no measurement has been made by the last day of a period referred to in that subsection — but, on that day, the compressor is not operating, in the case of a centrifugal compressor, or the compressor is not pressurized, in the case of a reciprocating compressor — the measurement must be made under that subsection on or before the 30th day after the day on which the compressor is next operating or pressurized, as the case may be. Extension — pressurized for < 1,314 hours per 3 years (6) Despite subsection (3), a period referred to in that subsection is extended by 365 days if the operator for the facility makes a record that demonstrates that, during the three calendar years immediately before the end of the period, the compressor was pressurized for less than 1,314 hours, as determined by an hour meter or as recorded in a log of operations.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 17
Continuous monitoring devices 17 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.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 18
Corrective action 18 (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. 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 m 3 /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 m 3 /min, and (ii) less than 5 MW, 0.34 standard m 3 /min. 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 m 3 /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 m 3 /min and the number of those pressurized cylinders. 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 m 3 , 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 m 3 , 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. 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 .
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 20
Application of sections 26 to 45 20 (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 m 3 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 m 3 , 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 m 3 , 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 m 3 , 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 . 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 .
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 21
Records — non-application 21 If none of sections 26 to 45 apply, for a given month, in respect of an upstream oil and gas facility, a record, with supporting documents, must be made that indicates (a) the gas-to-oil ratio and the volume of the hydrocarbon liquid produced or expected to be produced, expressed in standard m 3 , during the given month; (b) the combined volume of hydrocarbon gas produced and received, expressed in standard m 3 , during the given month; and (c) for a well at the facility that undergoes well completion during the given month, the volume expected to be produced by the well referred to in subsection 20 (2).
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 22
Records — application 22 A record must be made that indicates the following information for the first 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 m 3 of hydrocarbon gas for a period of 12 months as determined in accordance with subsection 20 (1): (a) that first month and the calendar year that includes that first month; and (b) the combined volume, along with an indication as to which of paragraphs 20 (1)(a) to (c) was used to determine that volume.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 23
Applicable methods 23 (1) For the purpose of sections 20 and 26 , the volume of hydrocarbon gas produced, received, vented or destroyed at, or delivered from, an upstream oil and gas facility must be determined in accordance with the applicable method set out in (a) the document entitled Measurement Guideline for Upstream Oil and Gas Operations , published by the Oil and Gas Commission of British Columbia on March 1, 2017, if the facility is located in British Columbia; (b) the document entitled Measurement Requirements for Oil and Gas Operations and commonly referred to as Directive PNG017, published by the Government of Saskatchewan on August 1, 2017 (version 2.1), if the facility is located in Manitoba or Saskatchewan; and (c) the document entitled Measurement Requirements for Oil and Gas Operations and commonly referred to as AER Directive 017, published by the Alberta Energy Regulator on March 31, 2016, in any other case. Directive PNG017 and AER 017 (2) Despite paragraphs (1)(b) and (c), for the purpose of sections 12.2.2.1 and 12.2.2.2 of the Saskatchewan Directive PNG017 and of the AER Directive 017, the gas production per well per day is to be determined (a) if the expected gas production is greater than 2 000 standard m 3 per day, by direct measurement; and (b) in any other case, (i) by direct measurement, or (ii) by means of an estimate based on a gas-to-oil ratio determined (A) in accordance with section 24 , or (B) by the formula −0.5P w + 150 where P w is the average volume, expressed in standard m 3 , of oil produced by the well for a day during the most recent month of production.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 24
500 standard m 3 per day and at most 1 000 standard m 3 per day, and (ii) in any other case, the flow rate of the gas according to the most recent determination was greater than 500 standard m 3 per day and at most 1 000 standard m 3 per day; and (c) at least once every month and at least seven days after a previous determination, if (i) in the case of an initial determination, the expected flow rate of the gas is greater than 1 000 standard m 3 per day and at most 2 000 standard m 3 per day, and (ii) in any other case, the flow rate of the gas according to the most recent determination was greater than 1 000 standard m 3 per day and at most 2 000 standard m 3 per day.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 25
Records 25 A record must be made that indicates (a) all of the readings from a continuous measuring device and each reading taken using a flow meter; (b) the flow rate over each period during which measurements were taken for each determination of the value of G and O; (c) the dates, time and duration of each of those periods; (d) the production parameters during each of those periods and the 48 hours before each of those periods begins; and (e) whether the type of equipment used to take each measurement was a continuous measuring device or a flow meter and its make and model.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 26
15 000 standard m 3 per year 26 (1) An upstream oil and gas facility must not vent more than 15 000 standard m 3 of hydrocarbon gas during a year. Excluded volumes (2) The volumes of hydrocarbon gas vented that arose from the following activities are excluded from the determination of the volume vented for the purpose of subsection (1): (a) liquids unloading, that is, the removal of accumulated liquids from a gas well; (b) a blowdown, that is, the temporary depressurization of equipment or pipelines; (c) glycol dehydration, that is, the use of a liquid desiccant system to remove water from natural gas or natural gas liquids; (d) the use of a pneumatic controller, pneumatic pump or compressor; (e) the start-up and shutdown of equipment; (f) well completion; and (g) venting in order to avoid serious risk to human health or safety arising from an emergency situation. Non-application of subsection (1) (3) Subsection (1) does not apply in respect of a facility, as of a given month, if the combined volume of hydrocarbon gas that was vented or destroyed at, or delivered from, the facility was less than 40 000 standard m 3 for the 12 consecutive months before that given month. Re-application of subsection (1) (4) Despite subsection (3), subsection (1) does apply in respect of a facility referred to in subsection (3), as of a subsequent month, if the combined volume of hydrocarbon gas that was vented or destroyed at, or delivered from, the facility was equal to or greater than 40 000 standard m 3 for the 12 consecutive months before that subsequent month.
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 27
Records — volumes of hydrocarbon gas 27 For each month that an upstream oil and gas facility operates, a record, with supporting documents, must be made that indicates (a) the volume of hydrocarbon gas that was vented, expressed in standard m 3 ; (b) the volume of hydrocarbon gas vented that arose from the activities referred to in each of paragraphs 26 (2)(a) to (g); (c) the volume of hydrocarbon gas destroyed at the facility, expressed in standard m 3 ; and (d) the volume of hydrocarbon gas delivered from the facility, expressed in standard m 3 .
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 28
Non-application to certain equipment components 28 (1) Sections 29 to 36 do not apply in respect of (a) an equipment component used on a wellhead at a site at which there is no other wellhead or equipment except for gathering pipelines or a meter connected to the wellhead; (b) a pair of isolation valves on a transmission pipeline if no other equipment is located on the segment of the pipeline that may be isolated by closing the valves; and (c) an equipment component used at an upstream oil and gas facility whose inspection would pose a serious risk to human health or safety. Record (2) A record must be made that indicates whether an equipment component is an equipment component referred to in any of paragraphs (1)(a) to (c).
Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (Upstream Oil and Gas Sector) — 29
Regulatory or alternative LDAR programs 29 (1) An operator for a facility must — in order to limit fugitive emissions containing hydrocarbon gas from equipment components at the facility — establish and carry out at the facility (a) a regulatory leak detection and repair program that satisfies the requirements of sections 30 to 33 ; or (b) an alternative leak detection and repair program referred to in subsection 35 (1) that results in at most the same quantity of those fugitive emissions as would result from a regulatory program referred to in paragraph (a), as demonstrated in a record, with supporting documents, made by the operator before the program is established and, at least once per year and at least 90 days after a previous demonstration, while the program is being carried out. Notice to Minister (2) An operator for a facility that establishes a leak detection and repair program referred to in paragraph (1)(b) must, without delay, notify the Minister to that effect.