Petroleum refining - Industry standard
Version 3.0 Created June 10, 2020
Preamble
- This technical standard is an industry standard as defined in section 1 of O. Reg. 419/05.
- With respect to facilities, this industry standard applies to every facility that is part of a class identified by one or more of the following NAICS codes: 324110 (Petroleum Refineries) and 324190 (Other Petroleum and Coal Product Manufacturing). If the activities identified by NAICS code 412110 (Petroleum Product Wholesaler-Distributors) take place on the same property as activities identified by NAICS code 324110 (Petroleum Refineries) or 324190 (Other Petroleum and Coal Product Manufacturing), then the facility is part of two or more classes that are identified by NAICS codes, and this industry standard applies to all of those classes. See also, section 4 of O. Reg. 419/05 regarding properties that are deemed to be a single property.
- For clarity, if a facility is part of a class identified by NAICS code 412110 (Petroleum Product Wholesaler-Distributors) and not on the same property as a facility that is part of a class identified by NAICS code: 324110 (Petroleum Refineries) or 324190 (Other Petroleum and Coal Product Manufacturing), this industry standard does not apply to the facility.
- With respect to contaminants, this industry standard applies to contaminants listed in Appendix 6-A.
- Each source of contaminant associated with NAICS codes 324110, 324190 and, if on the same property, 412110 that discharges a contaminant mentioned in the above bullet has been considered in development of this industry standard. As such, a person that meets the criteria set out in subsection 42 (1) or subsection 44 (1) of O. Reg. 419/05 is, in general, exempt from Part II of the Regulation in respect of the facility and contaminant(s) for which it is registered. In other words, there is no need to model, in a facility’s Emission Summary and Dispersion Modelling report, discharges of a registered contaminant from any source of contaminant associated with NAICS codes 324110, 324190 and, if on the same property, 412110. (For more information, please see the Introduction to the Technical Standards Publication.)
- In accordance with subsection 38 (3) of O. Reg. 419/05, compliance with this industry standard, in accordance with subsection 42 (5) or subsection 44 (3) of O. Reg. 419/05, may reduce the regulatory burden applicable to facilities in this class.
- This standard contains requirements that relate to sources of contaminant associated with the following:
- storage vessels
- equipment leaks
- sewage treatment operations
- truck and railcar product loading racks and marine vessel loading berths
- For this industry standard, with respect to benzene, the publication of this industry standard indicates that the following criteria of paragraph 3 of subsection 38 (1) of O. Reg. 419/05 are met:
- with respect to at least two facilities located in Ontario to which this standard applies, it is not technically feasible to comply with section 20 of O. Reg. 419/05; and
- compliance, in accordance with subsection 42 (5) of O. Reg. 419/05, with this standard,
- is technically and economically feasible with respect to at least one facility located in Ontario to which this industry standard applies,
- will permit efforts that would otherwise be made to comply with section 19 or 20 of O. Reg. 419/05 to be put to better use to protect the natural environment, having regard to clause (a), and
- including this industry standard in the “Technical Standards to Manage Air Pollution” is more efficient than having the Director consider separate requests under section 32 of O. Reg. 419/05 to set site-specific standards for the contaminant that would otherwise apply to facilities in the class.
Part I – General
Definitions
1. (1) For the purposes of this industry standard for petroleum refining facilities,
- “Act”
- means the Environmental Protection Act;
- “air pollution control device”
- means a device that removes contaminants from a gaseous stream and includes a carbon adsorber, a hermal oxidizer, a flare, a condenser, an absorber and an incinerator;
- “benzene-containing product”
- means a substance produced by a petroleum refining facility that contains two% or more benzene by weight, and includes gasoline;
- “bottoms receiver”
- means a tank that collects distillation bottoms;
- “carbon adsorber”
- means an air pollution control device which uses a bed of activated carbon to adsorb contaminants including VOCs;
- “cargo tank”
- means a container, including all associated pipes and fittings, that is designed to contain liquid product and is constructed to be part of a transportation system, including a truck, railcar or marine vessel;
- “CAS No.”
- has the same meaning as in subsection 1 (1) of O. Reg. 419/05;
- “catalytic oxidizer”
- means a technology that passes a gas over a support material coated with a catalyst that promotes oxidation of organic material in the gas;
- “closed system”
- means a system of piping, ductwork and connections that conveys a gas or vapour from a point of generation to another location without discharging the gas or vapour into the air;
- “component”
- means an apparatus that is part of an industrial process and includes a compressor, a pump, a valve, a pressure relief device, a sample point, an instrumentation system, an agitator and a connector;
- “cooling water effluent”
- has the same meaning as in O. Reg. 537/93;
- “connector”
- means a flanged, screwed or other joined fitting used to connect two pipes or a pipe and a piece of equipment. For the purpose of this industry standard, joined fittings welded completely around the circumference of the component interface are not considered connectors;
- “deck cover”
- means a device that stops contaminants from being discharged to the air from an opening on a floating roof deck;
- “deck fitting”
- means a piece of equipment that is inserted through an opening in a floating roof deck and includes, a sample port, a vacuum breaker, a deck leg, an access hatch, a deck drain, an access ladder well, a fixed-roof support column, an unslotted guidepole and a slotted guidepole;
- “distillation bottoms”
- Mis the portion of crude oil raw material that is discharged from the bottom of the distillation column;
- “distillation column”
- is a column that heats and separates crude oil raw material into components with differing boiling points;
- “drain”
- means a work that collects and transmits sewage to a sewer line;
- “existing storage vessel”
- means a storage vessel that,
- was installed at a petroleum refining facility before January 1, 2018, and
- has not undergone a major modification after January 1, 2018;
- “external floating roof”
- means a floating roof located in a storage vessel or an oil-water separator without a fixed roof;
- “flare”
- means a combustion device that uses an uncontrolled volume of air to burn gases. A flare includes the foundation, flare tip, structural support, burner, igniter, flare controls, air injection or steam injection systems, flame arrestors and the flare gas header system;
- “fixed leak detection system”
- means a permanently located system of sensors that are electrically linked to an analyzer and an electronic data acquisition system. For example, a fixed leak detection system may be located near a component, sample the air at regular time intervals and analyze and record the concentration of VOCs discharged to the air from the leaking component;
- “gasoline”
- means a petroleum distillate or a petroleum distillate and alcohol blend, having a Reid vapour pressure of 40 kilopascals or greater, that may be used as a fuel for an internal combustion engine;
- “inaccessible component”
- means a component that is located,
- at least two metres above a permanently available support surface,
- in such a manner that scaffolding or a harness is required in order to access the component, or
- in such a manner that the component is made inaccessible by a protective cover or insulation;
- “internal floating roof”
- means a floating roof located in a storage vessel or an oil-water separator with a fixed roof;
- “loading berth”
- means the loading arms, pumps, meters, shutoff valves, relief valves and other piping and valves used to load product into a marine vessel cargo tank;
- “loading rack”
- means the loading arms, pumps, meters, shutoff valves, relief valves and other piping and valves used to load product into a truck or railcar cargo tank;
- “low emission valve”
- means a valve that minimizes the discharge of contaminants from the valve to the natural environment;
- “low emission valve packing”
- means a material that minimizes the discharge of contaminants from a valve to the natural environment;
- “liquid-mounted rim seal”
- means a rim seal that is foam-filled or liquid-filled and is designed to be in contact with liquid stored in a storage vessel or an oil-water separator;
- “maintenance access point”
- means an access point to a sewer line, sometimes referred to as a person-hole, junction box, maintenance hole, manhole, or grate;
- “major modification”
- means a modification to a piece of equipment, the capital cost of which is at least 50% of the capital cost of replacing the equipment with a piece of equipment of the same size;
- “mechanical shoe rim seal”
- means a rim seal consisting of,
- a band of metal, or other suitable material, that is in sliding contact with the wall of a storage vessel or oil-water separator and which extends into the liquid stored in the vessel or separator, and
- a fabric seal to close the annular space between the band and the floating roof deck of the storage vessel or oil-water separator;
- “Minister”
- means the Minister of the Environment and Climate Change or such other member of the Executive Council as may be assigned the administration of this Act under the Executive Council Act;
- “Ministry”
- means the ministry of the Minister;
- “oil-water separator”
-
means a works in a sewage treatment system that separates free oil from sewage and consists of one or more of each of the following:
- Influent flumes or other inlet conduits.
- Separation zones.
- Effluent flumes or other outlet conduits.
-
Ancillary components which may include:
- Forebays.
- Skimmers.
- Baffles.
- Weirs.
- Grit chambers.
- Sludge hoppers.
- Bar screens;
- “open-ended valve”
- means a valve, except a pressure relief valve, having one side of the valve seal in contact with process fluid and one side open to the air, either directly or through open piping;
- “OGI instrument”
- means an instrument that makes emissions, that may otherwise be invisible to the naked eye, visible through the use of optical gas imaging;
- “primary oil-water separator”
-
means an oil-water separator that separates free oil from sewage that,
- has not passed through an oil-water separator upstream; and
- is not solely cooling water effluent, storm water effluent, or a combination of cooling water effluent and storm water effluent;
- “primary rim seal”
- means,
- a rim seal on a floating roof that has only one rim seal, or
- the lower rim seal on a floating roof that has two rim seals;
- “petroleum refining facility”
- means a facility which is part of a class identified by one or more of the following NAICS codes: 324110 and 324190. A petroleum refining facility includes activities described by NAICS code 412110 if the activities take place on the same property as the activities described by NAICS codes 324110 or 324190;
- “portable gas detector”
- means a handheld instrument that, when passed over a leaking component, measures the concentration of the gas leaking from the component;
- “product”
- means a substance, produced by a petroleum refining facility, that is intended to be sold or transferred;
- “registered contaminant”
- means a contaminant that is discharged into the air from a facility if a person is registered in respect of this industry standard, the facility and the contaminant;
- “registered person”
- means a person that is registered on the Ministry’s Technical Standards Registry – Air Pollution in respect of this industry standard, a petroleum refining facility and one or more contaminants listed in Appendix 6-A;
- “residence time”
- means the average amount of time that a gas spends in a furnace and is calculated by dividing the volume of the furnace by the volumetric flow rate of the gas through the furnace;
- “rim seal”
- means a device attached to the rim of a floating roof deck that spans the annular space between the deck and the wall of the storage vessel;
- “secondary rim seal”
- means the upper rim seal on a floating roof that has two rim seals;
- “separation zone”
- means the structure in an oil-water separator in which the separation of free oil from sewage primarily takes place. It may also be known as a separation or separator bay, separation or separator tank, separation or separator chamber, separation or separator compartment, separation or separator channel, separation or separator cell, or separation or separator basin. In some oil-water separators, the separation zone is preceded by a forebay;
- “sewer line”
- means a work used to collect and transmit industrial sewage to a sewage treatment system and includes a lateral trunk line, a branch line, a ditch and a channel;
- “storage vessel”
- means a tank used to store liquid petroleum, liquid petroleum derivatives or liquid product;
- “storm water effluent”
- has the same meaning as in O. Reg. 537/93;
- “surge control vessel”
- means a vessel that is used to manage flow rates in a process;
- “thermal oxidizer”
- means a device in which a combustible waste gas passes over or around a burner flame into a chamber where oxidation of the waste gas is completed;
- “unsafe component”
- means a component that, if assessed for leaks, is likely to,
- expose personnel performing the assessment to imminent hazard from temperature, pressure or explosive process conditions; or
- lead to other dangerous circumstances as defined by the Occupational Health and Safety Act;
- “vapour-mounted rim seal”
- means a rim seal that is designed to not be in contact with liquid stored in a storage vessel or oil-water separator and includes foam-filled seals and flexible wiper seals;
- “volatile organic compound” (“VOC”)
- means an organic compound the composition of which makes it possible for the compound to evaporate under normal atmospheric conditions of temperature and pressure.
(2) For the purpose of this industry standard, a floating roof inside a storage vessel with a geodesic dome will be considered to be an internal floating roof.
(3) For the purpose of this industry standard, a component, surge control vessel or bottoms receiver is in benzene service if,
- before January 1, 2025, the component, surge control vessel or bottoms receiver may contain or come in contact with a liquid or gas that contains at least 2.0% benzene by weight; and
- on and after January 1, 2025, the component, surge control vessel or bottoms receiver may contain or come in contact with a liquid or gas that contains at least 0.8% benzene by weight.
(4) For the purpose of this industry standard, a storage vessel is in benzene service if,
- before January 1, 2025, the storage vessel stores liquid that has a benzene concentration of at least 2.0% by weight; and
- on and after January 1, 2025, the storage vessel stores liquid that has a benzene concentration of at least 1.0% by weight.
(5) For the purpose of this industry standard, a component is in heavy liquid service if the component contains a fluid,
- that is not in a gaseous state at operating conditions; and
- in which the percentage of pure organic compounds that have a vapour pressure of greater than 0.3 kPa at 20°C is less than 20% by weight.
(6) In this industry standard, a reference to the Director means,
- the Director appointed under section 5 of the Act in respect of the section of this industry standard in which the reference appears;
- [Revoked]; or
- if no Director described in clause (a) has been appointed in respect of a provision, any Director appointed under section 5 of the Act in respect of section 27.1 or paragraphs 2 or 3 of subsection 11 (1) of O. Reg. 419/05.
Application
2. (1) This industry standard applies, in accordance with subsections (2) and (3), to a person who is registered on the Ministry’s Technical Standards Registry – Air Pollution in respect of,
- this industry standard;
- a petroleum refining facility; and
- one or more of the contaminants listed in Appendix 6-A.
(2) If the person mentioned in subsection (1) is registered with respect to a petroleum refining facility and one or more of the contaminants listed in an Appendix set out in Column 1 of Table 6-2, the sections set out opposite the Appendix in Column 2 of Table 6-2 apply in respect of the person.
(3) A person mentioned in subsection (1) is required to comply with the sections of this industry standard that apply to the person in accordance with subsection (2) on or before the date the person registers on the Ministry’s Technical Standards Registry – Air Pollution unless a different date is specified in this industry standard.
Item | Column 1 Appendix |
Column 2 Applicable Sections |
---|---|---|
1. | Appendix 6-A: All Contaminants | 1, 2, 52 to 59, 64, 65, 67 |
2. | Appendix 6-B: Benzene | 3 to 51, 60 to 63, 66, 68 |
3. | Appendix 6-C: Benzo(a)pyrene | - |
Leak Measurement Instrumentation
3. A registered person shall ensure that,
- if this industry standard requires the use of a portable gas detector, the detector meets the criteria set out in subsection 2 (1) of Appendix 6-D and is used in a manner set out in section 3 of Appendix 6-D;
- if this industry standard requires the use of an OGI instrument, the instrument meets the criteria set out in section 1 of Appendix 6-E and is used in a manner set out in section 2 of Appendix 6-E; and
- if this industry standard requires the use of a fixed leak detection system, the system meets the criteria set out in section 1 of Appendix 6-F.
Part II – Performance
Closed systems
4. (1) Subject to subsections (2) and (3), where this industry standard requires benzene to be conveyed in a manner set out in this section, the registered person shall ensure that benzene is conveyed in a closed system to one or more of the following:
- A flare that meets the requirements set out in section 5.
- An air pollution control device, other than a flare, that meets the requirements set out in section 6.
- A process that uses the benzene in a manner that,
- recovers the benzene,
- incorporates the benzene into a product to be sold or transferred,
- converts the benzene into a substance that is not benzene, or
- is similar to the manner in which another substance is used in the process.
(2) Benzene that is required to be conveyed to a thermal oxidizer or catalytic oxidizer in accordance with paragraph 2 of subsection (1) does not need to be conveyed to the air pollution control device if the air pollution control device is being repaired or maintained and the total number of hours that the air pollution control device was repaired and maintained in the preceding 12-month period does not exceed 240 hours.
(3) Benzene that is required to be conveyed to a process in accordance with paragraph 3 of subsection (1) does not need to be conveyed to the process if the process is being repaired or maintained and the total number of hours that the process was repaired and maintained in the preceding 12-month period does not exceed 240 hours.
(4) When calculating the number of hours for the purpose of subsections (2) and (3), the time when a thermal oxidizer, catalytic oxidizer, or process is being repaired or maintained does not need to be included in the total number of hours if benzene is not being conveyed to the air pollution device or process during the time.
(5) The registered person shall ensure that each time an air pollution control device or process mentioned in subsection (2) or (3) is repaired or maintained, the following information is recorded:
- The date of the repair or maintenance.
- The duration of the repair or maintenance.
- A description of the repair or maintenance.
- The position title of the personnel who assigned an individual to complete the repair or completed the maintenance.
- An indication of whether benzene is being conveyed to the air pollution device or process during the repair or maintenance.
(6) If the thing from which the benzene is being conveyed in the closed system required by subsection (1) has a vent, the registered person shall ensure that the vent is closed.
Flare
5. On and after January 1, 2020, a flare mentioned in paragraph 1 of subsection 4 (1) shall have a pilot flame present when a substance is being conveyed to the flare.
Air pollution control devices
6. An air pollution control device mentioned in paragraph 2 of subsection 4 (1) shall meet at least one of the following criteria:
- The air pollution control device shall reduce the discharge of benzene to the air by at least 95% on a mass basis.
- The air pollution control device shall not discharge VOCs to the air in a concentration of greater than 20 ppm by volume on a dry basis, corrected to three% oxygen.
- If the air pollution control device is a thermal oxidizer, the gas in the thermal oxidizer shall be maintained at a temperature of at least 760°C for a residence time of at least 0.75 seconds.
- If the air pollution control device is a catalytic oxidizer, the gas in the catalytic oxidizer shall be maintained at a temperature of at least 400°C.
Requirement to detect leaks
7. A registered person shall ensure that each component leak survey performed under subsection 39 (1) detects leaks from every leaking component that is part of the component leak survey.
Notification – performance requirements
8. (1) The registered person shall ensure that, as soon as practicable, a provincial officer is notified in writing of any contravention of sections 4 or 7.
(2) No later than 30 days after notification is required to be given under subsection (1), the registered person shall ensure that the following information is submitted, in writing, to a provincial officer:
- The date and time of the contravention.
- The details of the contravention, including any measured or calculated values relating to an exceedence of a limit.
- An explanation of suspected cause of the contravention, including the suspected cause of each exceedence of a limit, if any.
- A description of any steps taken, or that will be taken, to prevent, minimize or reduce the risk of future contraventions.
Part III – Storage Vessels
Storage vessels – identification
9. (1) A registered person shall ensure that each storage vessel at the petroleum refining facility is identified and recorded in accordance with this section.
(2) A record shall be made that sets out the following information for each storage vessel at the petroleum refining facility:
- The identification number of the storage vessel.
- A description of the liquid contained in the storage vessel, including the nominal% by weight of benzene in the liquid during the previous 12-month period.
(3) A list shall be prepared that identifies each storage vessel that meets the following criteria:
- The storage vessel has a design capacity of greater than 75 cubic metres.
- The storage vessel is designed to operate at an absolute internal pressure of less than 205 kilopascals.
- The storage vessel, in accordance with subsection (4), is, was or is anticipated to be in benzene service.
(4) In determining if the criterion mentioned in paragraph 3 of subsection (3) is met, the following information shall be considered:
- The concentration of benzene in the liquid stored in the storage vessel, for example the nominal% by weight of benzene in the liquid.
- The average concentration of benzene in the liquid stored in the storage vessel in the previous 12-month period.
- The anticipated concentration of benzene in the liquid to be stored in the storage vessel based on process information.
(5) The list required by subsection (3) shall be updated in accordance with the following rules:
- No later than 30 days after a change is made at the petroleum refining facility that results in a storage vessel meeting the criteria set out in subsection (3), the storage vessel shall be added to the list required by subsection (3).
- If a change is made at the petroleum refining facility that results in a storage vessel no longer meeting the criteria set out in subsection (3), the registered person shall ensure that the Director and a provincial officer are notified of the change at least 30 days before the storage vessel is removed from the list required by subsection (3).
- If, on or after January 1, 2025, a storage vessel meets the criteria set out in subsection (3), the storage vessel shall be added to the list required by subsection (3).
(6) The notification required by paragraph 2 of subsection (5) shall include all information relevant to demonstrating that the storage vessel no longer meets the criteria set out in subsection (3).
(7) No later than January 1, 2023, a record shall be prepared that sets out each storage vessel at the petroleum refining facility that is anticipated to meet the criteria set out in subsection (3) on or after January 1, 2025.
(8) No later than 60 days after a change is made at the petroleum refining facility that would affect the information in the record required by subsection (2), the record shall be updated to reflect the change.
Storage vessels - application
10. (1) Subject to subsection (4), on and after January 1, 2018, a registered person shall ensure that each storage vessel identified on the list required by subsection 9 (3) meets at least one of the following criteria:
- Subject to subsection (2), the storage vessel shall be equipped with an internal floating roof that meets the requirements set out in sections 12 and 14.
- Subject to subsection (3), the storage vessel shall be equipped with an external floating roof that meets the requirements set out in sections 13 and 14.
- Benzene which would otherwise be discharged from the storage vessel to the air shall be conveyed in a manner set out in section 4.
(2) The requirements set out in sections 12 and 14 do not apply to an existing storage vessel equipped with an internal floating roof.
(3) The requirements set out in sections 13 and 14 do not apply to an existing storage vessel equipped with an external floating roof unless,
- the date is on or after January 1, 2020 and the vessel stores liquid which has an annual average benzene concentration of more than 50% by weight;
- the date is on or after January 1, 2025 and the vessel stores liquid which has an annual average benzene concentration of more than four% by weight; or
- the date is on or after January 1, 2029.
(4) Subsection (1) does not apply to an existing storage vessel equipped with a fixed roof unless,
- the date is on or after January 1, 2020 and the vessel stores liquid which has an annual average benzene concentration of more than 50% by weight;
- the date is on or after January 1, 2025 and the vessel stores liquid which has an annual average benzene concentration of more than four% by weight; or
- the date is on or after January 1, 2029.
Floating roof - requirement to float
11. (1) A registered person shall ensure that for each storage vessel that is required to comply with paragraph 1 or 2 of subsection 10 (1), the floating roof floats on the surface of the liquid stored in the storage vessel.
(2) As soon as practicable after a contravention of subsection (1), the registered person shall ensure that at least one of the following actions are taken:
- The storage vessel shall be filled so that the roof floats on the surface of the liquid stored in the storage vessel as required by subsection (1).
- The storage vessel shall be emptied of liquid.
(3) A registered person shall ensure that the following information is recorded with respect to each contravention of subsection (1):
- The identification number of the storage vessel.
- The date and time that the floating roof was identified as not floating.
- The date and time that an action required by subsection (3) was taken.
Internal floating roof – rim seal requirements
12. An internal floating roof mentioned in paragraph 1 of subsection 10 (1) shall have,
- a liquid-mounted rim seal;
- a mechanical shoe rim seal; or
- a vapour-mounted rim seal and a secondary rim seal.
External floating roof – rim seal requirements
13. (1) An external floating roof mentioned in paragraph 2 of subsection 10 (1) shall have,
- a liquid-mounted rim seal and a secondary rim seal; or
- a mechanical shoe rim seal and a secondary rim seal.
(2) The mechanical shoe rim seal mentioned in clause (1) (b) shall meet the following criteria:
- The top of the mechanical shoe rim seal shall be a minimum of 61 centimetres above the surface of the liquid stored in the storage vessel.
- The band of material of the mechanical shoe rim seal that is in sliding contact with the storage vessel shall extend into the liquid stored in the storage vessel.
Floating roof deck fittings
14. (1) The requirements set out in this section apply with respect to a floating roof mentioned in paragraphs 1 and 2 of subsection 10 (1) and subparagraph 3 i of subsection 25 (1).
(2) The lower edge of each deck fitting on a floating roof shall be below the surface of the liquid stored in the storage vessel or primary oil-water separator unless the deck fitting is an automatic bleeder vent, vacuum breaker vent or rim space vent.
(3) Each automatic bleeder vent, vacuum breaker vent and rim space vent shall be equipped with,
- a lid with a gasket;
- a pallet with a gasket; or
- a flapper with a gasket.
(4) The space between the floating roof deck and each fixed roof support column shall be filled by a flexible fabric sleeve seal or covered by a gasketed deck cover.
(5) Each ample well and deck drain shall be covered by,
- a slit fabric seal that covers at least 90% of the sample well or deck drain; or
- a gasketed deck cover.
(6) The space between the floating roof deck and each guidepole shall be filled by a pole wiper.
(7) Each slotted guidepole shall have,
- a pole float, where the height of the pole float is at or above the height of the pole wiper; or
- an internal pole sleeve.
(8) Each unslotted guidepole shall have a gasketed cap on the top of the guidepole.
(9) With respect to a deck fitting that is not mentioned in subsections (3) to (8), the space between the deck fitting and the floating roof deck shall be covered by a gasketed deck cover.
(10) A gasketed deck cover that covers an access hatch or gauge float well shall be bolted or fastened when closed.
Deck covers – requirement to be closed
15. (1) Subject to subsection (2), the registered person shall ensure that each deck cover required by section 14 is closed when the storage vessel contains liquid.
(2) Subsection (1) does not apply if the deck cover is required to be open to,
- gauge the liquid level in the storage vessel; or
- take a sample of the liquid in the storage vessel.
(3) Subject to subsection (4), the registered person shall ensure that each lid, pallet and flapper mentioned in subsection 14 (3) is closed when the storage vessel contains liquid.
(4) Subsection (3) does not apply if the lid, pallet or flapper is required to be open to relieve excess pressure or vacuum in the storage vessel.
(5) The pressure above or below which is to be considered excess for the purpose of subsection (4) shall be based on the recommendation of a professional.
(6) The source of the professional recommendation mentioned in subsection (5) shall be one of the following documents:
- An operating and maintenance manual provided by a manufacturer of storage vessels.
- Written instructions provided by a supplier of storage vessels.
- A letter from a manufacturer mentioned in paragraph 1 or supplier mentioned in paragraph 2, setting out the recommendation.
- A letter from a professional engineer setting out the recommendation, the rationale for the recommendation and a description of the relevant experience with respect to the recommendation being made. The engineer must have relevant experience with respect to pressure or vacuum in storage vessels.
Floating roof - visual inspection
16. (1) On and after January 1, 2018, a registered person shall ensure that each storage vessel identified on the list required by subsection 9 (3) that is required to comply with paragraph 1 or 2 of subsection 10 (1) is visually inspected in accordance with this section to determine if any of the defects set out in subsection (7) are present.
(2) The inspection required by subsection (1) shall include an inspection of each floating roof deck, each deck fitting and each rim seal.
(3) The inspection required by subsection (1) shall be performed from the top of the floating roof each time a storage vessel is empty.
(4) If during a five-year period, a storage vessel mentioned in subsection (1) that has an external floating roof has not been inspected under this section, the inspection required by subsection (1) shall be performed from the top of the floating roof no later than 30 days after the end of the five-year period.
(5) Subject to subsection (6), if during a five-year period, a storage vessel described in subsection (1) that has an internal floating roof has not been inspected under this section, the inspection required by subsection (1) shall be performed, no later than 30 days after the end of the five-year period, by observing the floating roof deck, each deck fitting and each rim seal through an opening in the fixed roof.
(6) The inspection mentioned in subsection (5) does not need to determine if the defects set out in paragraphs 5 to 9 of subsection (7) are present.
(7) The defects mentioned in subsection (1) include the following:
- Liquid on the floating roof of the storage vessel.
- A hole or tear in the rim seal of the storage vessel.
- A detachment of any part of the rim seal from either of two surfaces from which the rim seal is intended to minimize air emissions that is,
- greater than 30 centimetres in length, and
- visible from a distance of three metres or more.
- The roof is not floating on the surface of the liquid as required by subsection 11 (1).
- An opening for a fixed roof support column is not equipped with a fabric sleeve or gasketed deck cover.
- A sample well is not equipped with a slit fabric seal.
- A guidepole does not have a pole wiper, pole float, internal pole sleeve or gasketed cap, as applicable.
- The lower edge of a deck fitting, other than an automatic bleeder vent, vacuum breaker vent or rim space vent, is not below the surface of the liquid.
- The top of a mechanical shoe rim seal is less than 61 centimetres above the surface of the liquid stored in the storage vessel.
Storage vessels - OGI inspection
17. (1) On and after January 1, 2018, a registered person shall ensure that each storage vessel identified on the list required by subsection 9 (3) is inspected in accordance with this section.
(2) Subject to subsection (3), at least one time in every four-month period the registered person shall ensure that each storage vessel mentioned in subsection (1) is inspected using an OGI instrument to determine if VOCs are being discharged to the air from leaks in the storage vessel, including from leaks in the floating roof.
(3) Subsection (2) does not apply to a storage vessel that has been empty for the four-month period.
Floating roof - seal gap inspection
18. (1) On and after January 1, 2018, the registered person shall ensure that the following actions are performed, in accordance with this section, with respect to each storage vessel identified on the list required by subsection 9 (3) that is required to comply with paragraph 2 of subsection 10 (1)
- Inspect each rim seal to identify each gap between the rim seal and the two surfaces from which the rim seal is intended to minimize air emissions in accordance with the procedure set out in subsection (3).
- Inspect each deck fitting to identify each gap between a deck fitting gasket and the two surfaces from which the gasket is intended to minimize air emissions in accordance with the procedure set out in subsection (4).
- Determine the ratio of accumulated area of rim seal gaps to storage vessel diameter in accordance with the procedure set out in subsection (5).
(2) The actions required by subsection (1) shall be performed each time a storage vessel is empty.
(3) Each location where a 0.32 centimetre diameter probe passes freely between the following surfaces shall be identified as a gap for the purpose of paragraph 1 of subsection (1):
- The rim seal and the storage vessel wall.
- The rim seal and the floating deck rim.
(4) Each location where a 0.32 centimetre diameter probe passes freely between the following surfaces shall be identified as a gap for the purpose of paragraph 2 of subsection (1):
- The gasket and the floating deck.
- The gasket and the deck fitting.
(5) The ratio of accumulated area of rim seal gaps to storage vessel diameter mentioned in paragraph 3 of subsection (1) shall be determined in accordance with the following procedure:
- Identify each gap in the rim seal by inserting a 0.32 centimetre diameter probe between the rim seal and the storage vessel wall. Each location where the probe passes freely between the rim seal and the vessel wall constitutes a rim seal gap.
- Slide the probe along the storage vessel wall in each direction as far as it will travel freely without binding between the rim seal and the storage vessel wall. The circumferential length along which the probe can move freely is the rim seal gap length.
- Insert probes, the diameters of which increase in increments of 0.32 centimetres, between the rim seal and the storage vessel wall. The diameter of the largest probe that can be inserted freely anywhere along the length of the gap is the maximum rim seal gap width.
- Determine the average width of each rim seal gap by averaging the minimum and maximum rim seal gap width.
- Calculate the area of a rim seal gap by multiplying the rim seal gap length determined under paragraph 2 by the average rim seal gap width determined under paragraph 4.
- Repeat steps 2 to 5 for each rim seal gap identified under paragraph 1.
- Calculate the ratio of accumulated area of rim seal gaps to storage vessel diameter by adding the area of each rim seal gap determined under paragraphs 5 and 6 and dividing the sum by the diameter of the storage vessel.
Storage vessel repair
19. (1) A registered person shall ensure that each defect and gap is repaired in accordance with this section if,
- an inspection required by subsection 16 (1) indicates a defect listed in subsection 16 (7);
- an inspection required by subsection 17 (1) indicates that VOCs are being discharged to the air from leaks in the storage vessel;
- an inspection required by paragraph 1 or 2 of subsection 18 (1) indicates one or more gaps; or
- a re-inspection required by subsection (5) indicates that a repair required under this subsection did not stop a leak.
(2) Each defect and gap required to be repaired by subsection (1) shall be repaired,
- prior to re-filling the storage vessel, if the inspection is performed while the storage vessel is not storing liquid; or
- subject to subsection (3), no later than 200 days after the date of the inspection, if the inspection is performed while the storage vessel is storing liquid.
(3) Clause (2) (b) does not apply if the storage vessel is completely emptied and de-gassed no later than 200 days after the date of the inspection.
(4) The registered person shall ensure that each defect or gap is repaired prior to re-filling a storage vessel described in subsection (3).
(5) The registered person shall ensure that no later than 20 days following the repair required under subsection (1), the storage vessel is re-inspected using an OGI instrument to determine whether the repair has stopped the leak.
Requirement to notify – recurring repairs
20. (1) If a defect or gap in a floating roof of a storage vessel at a petroleum refining facility is required to be repaired by subsection 19 (1), and two or more repairs have been required by subsection 19 (1) in respect of the same storage vessel in the preceding 24-month period, the registered person shall ensure that a provincial officer is notified in writing no later than five days after the inspection that identified the defect or gap.
(2) No later than 30 days after notification is required to be given under subsection (1), the registered person shall ensure that the following information is submitted, in writing, to a provincial officer:
- A description of each gap or defect.
- A description of the repair made.
- An explanation of steps taken to prevent, minimize or reduce, the chance of the defect or gap recurring in the future.
Storage vessels in benzene service – general record
21. A registered person shall ensure that the following information is recorded for each storage vessel identified on the list required by subsection 9 (3):
- The design capacity, in cubic metres, of the storage vessel.
- The absolute internal pressure, in kilopascals, at which the storage vessel is designed to operate.
- The date on which the storage vessel was last emptied.
- The date on which the storage vessel is next anticipated to be emptied.
- The type of roof on the storage vessel.
- If benzene from the storage vessel is conveyed in a manner set out in section 4, a description of how and to where the benzene is conveyed.
Storage vessel inspection record
22. A registered person shall ensure that the following information is recorded for each inspection required by subsections 16 (1), 17 (1), 18 (1) and 19 (5):
- The identification number of the storage vessel for which the inspection was conducted.
- The date of the inspection.
- The type of inspection performed.
- The position title of the personnel who assigned an individual to perform the inspection.
- The results of the inspection, including the following information:
- If the inspection was an inspection required by subsection 16 (1), a summary of any defects observed during the inspection.
- If the inspection was an inspection required by subsection 17 (1) and it was determined that VOCs were being discharged to the air, a copy of the image produced by the OGI instrument.
- If the inspection was an inspection required by subsection 18 (1), all gaps identified in accordance with subsections 18 (3) and (4) and the ratio of accumulated area of rim seal gaps to storage vessel diameter calculated in accordance with paragraph 7 of subsection 18 (5).
- A description of any repairs required by section 19, including the date that the repair was made.
- A copy of the image produced by the OGI instrument in the re-inspection required by subsection 19 (5).
Rim seal gap report – storage vessels
23. (1) No later than 30 days after an inspection required by subsection 18 (1) indicates that one or more of the following criteria are met, the registered person shall ensure that a report is prepared in accordance with subsection (2):
- The ratio of accumulated area of rim seal gaps to storage vessel diameter exceeds 212 square centimetres per metre with respect to a primary rim seal.
- The ratio of accumulated area of rim seal gaps to storage vessel diameter exceeds 21.2 square centimetres per metre with respect to a secondary rim seal.
(2) The report mentioned in subsection (1) shall include the following information:
- The date of the inspection that identified the rim seal gaps used to calculate the ratio mentioned in subsection (1).
- The date of the previous inspection required by subsection 18 (1).
- A description of the results of the inspection that identified the rim seal gaps mentioned in paragraph 1, including the area of each rim seal gap identified in the inspection.
- A description of a plan of repair, including the anticipated date of the repair required by clause 19 (1) (c).
- A written record indicating that the highest-ranking individual at the petroleum refining facility has reviewed that the report has been prepared in accordance with this industry standard.
Part IV – Air Emissions From Industrial Sewage
Application, sections 24 and 25
23.1. (1) Sections 24 and 25 do not apply to a device if it is used as a primary oil-water separator for no more than 240 hours in the preceding 12-month period.
Primary oil-water separators – requirement selection
24. (1) A registered person shall elect, in writing to the Director, with respect to each primary oil-water separator at the petroleum refining facility, whether the primary oil-water separator will meet the requirements set out in paragraph 1, 2 or 3 of subsection 25 (1).
(1.1) The election mentioned in subsection (1) shall be made or amended by the later of the following dates:
- March 1, 2018.
- The date the primary oil-water separator is first used at the facility.
(2) If a registered person does not make or amend an election in accordance with subsection (1.1) with respect to a primary oil-water separator, the registered person is deemed to have elected that the primary oil-water separator will meet the requirements set out in paragraph 3 of subsection 25 (1).
(3) If a registered person elects under subsection (1) that a primary oil-water separator will meet the requirements set out in paragraphs 1 or 2 of subsection 25 (1), the registered person may change the election, in writing to the Director, to elect that the primary oil-water separator will meet the requirements set out in paragraph 3 of subsection 25 (1).
(4) Unless a registered person is required to comply with subsection (5), the registered person shall ensure that each primary oil-water separator at a petroleum refining facility meets the requirements set out in the paragraph of subsection 25 (1) that the registered person elected under this section.
(5) No later than 24 months after a primary oil-water separator meets one or more of the following criteria, a registered person shall ensure that the primary oil-water separator meets the requirements set out in paragraph 3 of subsection 25 (1):
- The annual average concentration of benzene measured by a monitor required by paragraph 1 of subsection 25 (1) in respect of the primary oil-water separator, determined in accordance with subsection 25 (2.1), is greater than 5.0 micrograms per cubic metre.
- The annual average emission rate of benzene from the primary oil-water separator, determined in accordance with paragraph 2 of subsection 25 (1), is greater than 2.0 milligrams per second.
Primary oil-water separators – monitoring and control requirements
25. (1) A registered person shall ensure that each primary oil-water separator at a petroleum refining facility meets at least one of the following requirements, in accordance with section 24:
- On and after July 1, 2018, the concentration of benzene in the air shall be measured in accordance with subsection (2) by at least one ambient monitor that is located no more than 200 metres and no less than 100 metres downwind of the primary oil-water separator and the annual average concentration of benzene measured by a monitor shall be determined in accordance with subsection (2.1).
- On and after July 1, 2018, the parameters in Table 6-25 shall be measured or otherwise determined and the annual average emission rate of benzene from the primary oil-water separator shall be determined, all in accordance with subsection (3).
- Subject to subsection (6), on and after January 1, 2019, the primary oil-water separator shall meet at least one of the following criteria:
- Each separation zone of the primary oil-water separator shall be equipped with an internal or external floating roof that meets the requirements set out in subsection (5).
- Benzene which would otherwise be discharged to the air from each separation zone of the primary oil-water separator shall be conveyed in a manner set out in section 4.
(2) A monitor mentioned in paragraph 1 of subsection (1) shall be located and operated in accordance with a plan that, in the opinion of the Director, is adequate to result in the effective measurement of the concentration of benzene in the air in the vicinity of the primary oil-water separator.
(2.1) The annual average concentration of benzene measured by a monitor mentioned in paragraph 1 of subsection (1) shall, subject to subsection (2.2), be based on the measurements taken during the period from January 1 to December 31 in a year and shall be determined before March 31 in the following year.
(2.2) The first time the annual average concentration of benzene measured by a monitor is determined under paragraph 1 of subsection (1), the concentration shall be based on the first 12 months of measurements and shall be determined before the date that is three months after the end of the 12-month period.
(3) The annual average emission rate of benzene mentioned in paragraph 2 of subsection (1) shall:
- be determined in accordance with a plan that, in the opinion of the Director, meets the requirements set out in subsection (4) and is adequate to result in the effective determination of the emission rate; and
- subject to subsection (3.1), be based on the measurements taken during the period from January 1 to December 31 in a year and shall be determined before March 31 in the following year.
(3.1) The first time the annual average emission rate of benzene is determined under paragraph 2 of subsection (1), the rate shall be based on the first 12 months of measurements and shall be determined before the date that is three months after the end of the 12-month period.
(4) The plan mentioned in subsection (3) shall meet the following requirements:
- The plan shall require that the annual average emission rate of benzene be calculated by taking the average of benzene emission rates calculated for each week based on the parameters set out in Column 1 of Table 6-25.
- The plan shall require that each parameter set out in Column 1 of Table 6-25 is determined in accordance with the rules set out opposite the parameter in Column 2 of the Table.
- Despite paragraph 2, the parameters set out in Column 1 of Table 6-25 may be determined each calendar month instead of each week if each annual average emission rate of benzene from the primary oil-water separator calculated with respect to the preceding two calendar years is no more than 1.0 milligram per second.
- Despite paragraph 1, if the parameters set out in Column 1 of Table 6-25 are determined each calendar month instead of each week, the annual average emission rate of benzene shall be calculated by taking the average of benzene emission rates calculated for each month based on the parameters set out in Column 1 of Table 6-25.
Item | Column 1 Parameter |
Column 2 Determination Rules |
---|---|---|
1. | The flow rate of sewage entering the primary oil-water separator |
|
2. | The concentration of benzene in the sewage entering the primary oil-water separator |
|
3. | The flow rate of sewage leaving the primary oil-water separator |
|
4. | The concentration of benzene in the sewage leaving the primary oil-water separator |
|
5. | The removal rate of skimmed oil waste from the primary oil-water separator |
|
6. | The concentration of benzene in the skimmed oil waste removed from the primary oil-water separator |
|
7. | The removal rate of waste sludge from the primary oil-water separator |
|
8. | The mass fraction, on a dry-weight basis, of benzene in the waste sludge removed from the primary oil-water separator |
|
9. | The concentration of Total Solids in the waste sludge removed from the primary oil-water separator |
|
(5) A registered person shall ensure that each primary oil-water separator at a petroleum refining facility that is required to comply with subparagraph 3 i of subsection (1) complies with the following requirements:
- The floating roof shall have a secondary rim seal and,
- a liquid-mounted rim seal, or
- a mechanical shoe rim seal.
- Each deck fitting on the floating roof shall comply with the requirements set out in section 14.
- If the floating roof has a deck drain, each deck drain shall be fitted with,
- a slotted membrane fabric cover that covers at least 90% of the deck drain,
- a flexible fabric sleeve seal, or
- a gasketed deck cover.
(6) If a separation zone has a device, such as a skimmer, that is required to operate at or above the liquid surface, paragraph 3 of subsection (1) does not apply to the portion of the separation zone in which the device operates at or above the liquid surface if the surface area of the portion is negligible relative to the surface area of the separation zone.
(7) For the purposes of this section, “accumulation period” means the period of time since the last time that skimmed oil waste or waste sludge was removed from the primary oil-water separator.
Primary oil-water separators floating roof – requirement to float
26. (1) A registered person shall ensure that for each primary oil-water separator that is required to comply with subparagraph 3 i of subsection 25 (1), the floating roof floats on the surface of the liquid contained in the separation zone of the primary oil-water separator.
(2) As soon as practicable after a contravention of subsection (1), the registered person shall ensure that the primary oil-water separator is filled so that the roof floats on the surface of the liquid contained in the separation zone of the primary oil-water separator.
(3) The registered person shall ensure that a record of the following information is made with respect to each contravention of subsection (1):
- The identification number of the primary oil-water separator.
- The date and time that the floating roof was identified as not floating.
- The date and time that an action required by subsection (2) was taken.
Primary oil-water separators floating roof – rim seal gap inspection
27. (1) For each primary oil-water separator at a petroleum refining facility that is required to comply with subparagraph 3 i of subsection 25 (1) and which is equipped with an external floating roof, the registered person shall ensure that the following actions are performed in accordance with this section:
- Inspect the primary rim seal to identify each gap between the rim seal and the primary oil-water separator wall in accordance with the procedure set out in subsection (4).
- Determine the maximum rim seal gap width of each primary rim seal gap and determine the ratio of accumulated area of primary rim seal gaps to perimeter of the floating roof in accordance with the procedure set out in subsection (5).
- Inspect the secondary rim seal to identify each gap between the rim seal and the primary oil-water separator wall in accordance with the procedure set out in subsection (4).
- Determine maximum rim seal gap width of each secondary rim seal gap and determine the ratio of accumulated area of secondary rim seal gaps to perimeter of the floating roof in accordance with the procedure set out in subsection (5).
(2) The actions required by paragraphs 1 and 2 of subsection (1) shall be performed,
- no later than 60 days after the later of,
- the date that sewage is first deposited in a primary oil-water separator at a petroleum refining facility, and
- the date that the registered person is required to comply with subparagraph 3 i of subsection 25 (1); and
- no less than one time in every five-year period following the inspection required by clause (a).
(3) The actions required by paragraphs 3 and 4 of subsection (1) shall be performed,
- no later than 60 days after the later of,
- the date that sewage is first deposited in a primary oil-water separator at a petroleum refining facility, and
- the date that the registered person is required to comply with subparagraph 3 i of subsection 25 (1); and
- no less than one time in every one-year period following the inspection required by clause (a).
(4) Each location where a 0.32 centimetre diameter probe passes freely between a rim seal and the primary oil-water separator wall shall be identified as a gap for the purpose of paragraphs 1 and 3 of subsection (1).
(5) The ratio of accumulated area of rim seal gaps to perimeter of the floating roof mentioned in paragraphs 2 and 4 of subsection (1) shall be determined in accordance with the following procedure:
- Identify each gap in the rim seal by inserting a 0.32 centimetre diameter probe between the rim seal and the primary oil-water separator wall. Each location where the probe passes freely between the rim seal and the primary oil-water separator wall constitutes a rim seal gap.
- Slide the probe along the primary oil-water separator wall in each direction as far as it will travel freely without binding between the rim seal and the primary oil-water separator wall. The length along which the probe can move freely is the rim seal gap length.
- Insert probes, the diameters of which increase in increments of 0.32 centimetres, between the rim seal and the primary oil-water separator wall. The diameter of the largest probe that can be inserted freely anywhere along the length of the gap is the maximum rim seal gap width.
- Determine the average width of each rim seal gap by averaging the minimum and maximum rim seal gap.
- Calculate the area of a rim seal gap by multiplying the rim seal gap length determined under paragraph 2 by the average rim seal gap width determined under paragraph 4.
- Repeat steps 2 to 5 for each rim seal gap identified under paragraph 1.
- Calculate the ratio of accumulated area of rim seal gaps to perimeter of the floating roof by adding the area of each rim seal gap determined under paragraphs 5 and 6 and dividing the sum by the perimeter of the floating roof.
Primary oil-water Separator – OGI inspection
28. (1) A registered person shall ensure that each primary oil-water separator at a petroleum refining facility that is required to comply with paragraph 3 of subsection 25 (1) is inspected using an OGI instrument at least one time in every four-month period to determine if VOCs are being discharged to the air from leaks in the primary oil-water separator.
(2) If the primary oil-water separator mentioned in subsection (1) is required to comply with subparagraph 3 i of subsection 25 (1), the inspection required by subsection (1) shall inspect the floating roof to determine if VOCs are being discharged to the air from the floating roof.
Primary oil-water separator repair
29. (1) A registered person shall ensure that each defect and gap is repaired in accordance with this section if,
- an inspection required by subsection 27 (1) indicates one or more rim seal gaps;
- an inspection required by subsection 28 (1) indicates that VOCs are being discharged to the air from leaks in the primary oil-water separator; or
- a re-inspection required by subsection (3) indicates that a repair required under this subsection did not stop a leak.
(2) Each defect and gap required to be repaired by subsection (1) shall be repaired no later than 200 days after the date of the inspection.
(3) The registered person shall ensure that no later than 20 days following the repair required under subsection (1), the primary oil-water separator is re-inspected using an OGI instrument to confirm that the repair has stopped the leak.
Primary oil-water separator record - general
30. (1) A registered person shall ensure that the following information is recorded for each primary oil-water separator at the petroleum refining facility:
- Which requirement in subsection 25 (1) the primary oil-water separator is required to meet.
- If the registered person has elected that the primary oil-water separator will meet the requirement set out in paragraph 1 of subsection 25 (1):
- Each measurement taken by each ambient monitor.
- The date and time of each measurement mentioned in subparagraph i.
- The annual average of the concentration of benzene in the air measured by each ambient monitor.
- If the registered person has elected that the primary oil-water separator will meet the requirements set out in paragraph 2 of subsection 25 (1), the annual average emission rate of benzene from the primary oil-water separator and all measurements and calculations required by subsection 25 (3).
- If the registered person has elected that the primary oil-water separator will meet the requirement set out in paragraph 3 of subsection 25 (1), a description of the method set out in paragraph 3 of subsection 25 (1) associated with the primary oil-water separator.
(2) The records required by paragraphs 2 and 3 shall be made at the same time as when the measurement is taken or the calculation is made.
Primary oil-water separator inspection record
31. A registered person shall ensure that the following information is recorded for each inspection required by subsections 27 (1) and 28 (1):
- The primary oil-water separator for which the inspection was conducted.
- The date of the inspection.
- The type of inspection performed.
- The position title of the personnel who assigned an individual to perform the inspection.
- If the inspection was an inspection required by subsection 27 (1), the following information:
- Whether any primary rim seal gaps with a maximum rim seal gap width greater than 3.8 centimetres were identified.
- The ratio of accumulated area of primary rim seal gaps to perimeter of the floating roof.
- Whether any secondary rim seal gaps with a maximum rim seal gap width greater than 1.3 centimetres were identified.
- The ratio of accumulated area of secondary rim seal gaps to perimeter of the floating roof.
- If the inspection was an inspection required by subsection 28 (1) and it was determined that VOCs were being discharged to the air from the primary oil-water separator, a copy of the image produced by the OGI instrument.
- A description of any repairs required by section 29, including the date that the repair was made.
- A copy of the image produced by the OGI instrument in the re-inspection required by subsection 29 (3).
Rim seal gap report – primary oil-water separator
32. (1) No later than 30 days after an inspection required by subsection 27 (1) indicates that one or more of the following criteria are met, the registered person shall ensure that a report is prepared in accordance with subsection (2):
- The width of a rim seal gap in the primary rim seal of a primary oil-water separator equals or exceeds 3.8 centimetres.
- The ratio of accumulated area of primary rim seal gaps to perimeter of the floating roof exceeds 67 square centimetres per metre of primary oil-water separator wall.
- The width of a rim seal gap in the secondary rim seal of a primary oil-water separator exceeds 1.3 centimetres.
- The ratio of accumulated area of secondary rim seal gaps to perimeter of the floating roof exceeds 6.7 square centimetres per metre of primary oil-water separator wall.
(2) The report mentioned in subsection (1) shall include the following information:
- The date of the inspection that identified the rim seal gaps used to calculate the ratio mentioned in subsection (1).
- The date of the previous inspection required by subsection 27 (1) of the primary oil-water separator.
- A description of the results of the inspection that identified the rim seal gaps mentioned in paragraph 1, including the area of each rim seal gap identified in the inspection.
- A description of a plan of repair, including the anticipated date of the repair required by section 29.
- A written record indicating that the highest-ranking individual at the petroleum refining facility has reviewed that the report has been prepared in accordance with this industry standard.
Drains and maintenance access points – measurement and control requirements
33. (1) Subject to subsection (6), no later than July 1, 2019, a registered person shall take one of the actions set out in subsection (4) for each of the following things at the petroleum refining facility:
- Each drain that meets the criteria set out in subsection (2).
- Each maintenance access point that meets the criteria set out in subsection (3).
(2) A drain meets the criteria mentioned in paragraph 1 of subsection (1) if the drain is not used solely for storm water effluent and,
- is 200 metres or less from the property boundary of the facility; or
- is a drain that is directly connected by sewer line to a maintenance access point that is 200 metres or less from the property boundary of the facility.
(3) A maintenance access point meets the criteria mentioned in paragraph 2 of subsection (1) if the maintenance access point is 200 metres or less from the property boundary of the facility.
(4) The registered person shall take at least one of the following actions in accordance with the requirement set out in subsection (1):
- Implement a plan that, in the opinion of the Director, will minimize benzene emissions from the drain or maintenance access point.
-
Take one of the following actions for each drain and maintenance access point mentioned in subsection (1) in accordance with a plan that, in the opinion of the Director, would effectively determine the concentration, or highest potential concentration, of benzene in the sewage in the drain or maintenance access point:
- Measure the concentration of benzene in the sewage in the drain or maintenance access point.
- Determine the highest potential concentration of benzene in the sewage in the drain or maintenance access point by measuring the concentration of benzene in the sewage in an upstream drain or maintenance access point.
(5) No later than 18 months after a measurement mentioned in paragraph 2 of subsection (4) indicates that the annual average concentration of benzene in sewage is greater than 100 milligrams per litre, the registered person shall implement a plan mentioned in paragraph 1 of subsection (4).
(6) Subsection (1) does not apply with respect to a drain or maintenance access point if the Director is satisfied that the sewage in the drain or maintenance access point does not contain benzene.
(7) If a change may occur at the petroleum refining facility that may affect the concentration of benzene in the sewage in a drain or maintenance access point mentioned in subsection (6), the registered person shall notify the Director and provide the following information at least three months before the change is made:
- A description of the planned change.
- A description of how the planned change may affect the benzene concentration in the sewage in the drain or maintenance access point.
Drain and maintenance access point record
34. A registered person shall ensure that the following information is recorded:
- A map or schematic of the petroleum refining facility showing the location of each drain and maintenance access point mentioned in subsection 33 (1).
- For each drain and maintenance access point at the petroleum refining facility mentioned in subsection 33 (1),
- a description of how benzene emissions are minimized in accordance with paragraph 1 of subsection 33 (4), or
- the results of the measurements required by paragraph 2 of subsection 33 (4).
Part V – Product Loading
Benzene-containing product loading operations – application
35. (1) Subject to subsection (6), no later than March 31, 2018 and March 31 in each following year, the registered person shall ensure that the throughput of benzene-containing product for each loading rack and loading berth at a petroleum refining facility during the preceding calendar year, in litres per year, is determined and recorded.
(2) Subject to subsection (4), the registered person shall ensure that benzene which would otherwise be discharged to the air from a cargo tank in a loading rack is conveyed in a manner set out in section 4 if the loading rack has a throughput of 14 million litres of benzene-containing product per year or greater.
(3) Subject to subsection (4), the registered person shall ensure that benzene which would otherwise be discharged to the air from a cargo tank in a loading berth is conveyed in a manner set out in section 4 if the loading berth is located at a petroleum refining facility where the average total throughput of benzene-containing product for all loading berths at the petroleum refining facility is 1.6 billion litres per year or greater in a three-year period.
(4) Subsections (2) and (3) do not apply until the date that is 18 months after the throughput criteria has been met.
(5) For greater certainty, the requirements set out in subsections (2) and (3) do not cease to apply if, in a subsequent year, the loading rack or loading berth does not meet the throughput criteria set out in those subsections.
(6) Subsection (1) does not apply with respect to,
- a loading rack that meets or has previously met the throughput criteria set out in subsection (2); or
- a loading berth that meets or has previously met the throughput criteria set out in subsection (3).
Cargo tank loading operations – general operating requirements
36. A registered person shall ensure that the tank filling line used to load benzene-containing product into a cargo tank is placed no higher than 10 centimetres above the bottom of the cargo tank.
Vapour-tight cargo tanks
37. On or after July 1, 2018, a registered person shall ensure that vapour-tight cargo tanks are used when benzene-containing product is loaded into a cargo tank at the petroleum refining facility.
Part VI – Leak Detection and Repair
Component identification
38 (1) Subject to subsection (2), a registered person shall ensure that a written record is made of each of the following components at the petroleum refining facility if the component is in benzene service:
- A compressor.
- A pump.
- A valve.
- A pressure relief device.
- A sample point.
- An instrumentation system.
- An agitator.
- A connector.
(2) Subsection (1) does not apply to a component that,
- is operated at a pressure below atmospheric pressure;
- is a pump that is equipped with,
- a dual mechanical seal,
- a barrier fluid that is at a higher pressure than the operating pump pressure, and
- a system that alerts the operator when the seal or barrier fluid has failed; or
- is a valve or connector with a nominal diameter of less than 1.875 centimetres or ¾ of an inch.
(3) Subject to subsection (4), a registered person shall ensure that each component required to be recorded under subsection (1) is listed in a single electronic record with associated fields setting out the following information:
- The name and model number of the component.
- The name of the manufacturer of the component.
- The serial number of the component.
- The purpose of the component.
- The process unit of which the component is part.
- Whether the component is in heavy liquid service.
- Whether the component is an inaccessible component.
- If, in the opinion of the highest ranking individual at the petroleum refining facility, the component is an unsafe component, the basis for the opinion that the component is unsafe.
- The estimated percentage of benzene, by weight, to which the component is exposed.
- The date the component was installed.
- If the component replaced a component, the period of time the replaced component was in service.
(4) Paragraphs 1, 2, 3, 10 and 11 of subsection (3) do not apply with respect to a component that was installed prior to January 1, 2018 unless the component is a pump or a compressor.
(5) No later than 30 days after a change is made at the petroleum refining facility that would affect the information in the record required by subsection (3), the registered person shall ensure that the record is updated to reflect the change.
Component leak survey – general
39 (1) If the date is on or after January 1, 2018, a registered person shall ensure that a component leak survey is performed at the petroleum refining facility in accordance with this section.
(2) A component leak survey shall be completed,
- at least three times each calendar year with at least one component leak survey being completed during each of the following periods,
- the period starting April 1 and ending June 30,
- the period starting July 1 and ending September 30, and
- the period starting October 1 and ending December 31; or
- at least one time each calendar year if,
- the combined annual percentage of leaking valves in the previous calendar year, calculated in accordance with subsection 47 (1) is less than 1.0%, and
- the annual average concentration of VOCs from leaking components in the previous calendar year, calculated in accordance with subsection 47 (2), is less than 10,000 ppm.
(3) A component leak survey required by clause (2) (b) shall be completed no later than 90 days after the first component in the survey was assessed for leaks.
(4) Subject to subsection (5), a component leak survey required by subsection (1) shall assess each component required to be recorded under subsection 38 (1) to determine if the component is leaking.
(5) A component does not need to be included in a component leak survey if,
- the component was in benzene service for less than 300 hours in the previous calendar year and the registered person has recorded the hours that the component was in benzene service in the previous calendar year in accordance with paragraph 4 of subsection 48 (1);
- the component is identified in paragraph 6 of subsection 38 (3) as being in heavy liquid service;
- the date is on or before December 31, 2022 and the component is identified in paragraph 7 of subsection 38 (3) as inaccessible; or
- the component is identified in paragraph 8 of subsection 38 (3) as an unsafe component.
(6) No later than March 1 each year, the registered person mentioned in subsection (1) shall ensure that the Director and a provincial officer are given a written summary of the dates on which component leak surveys are anticipated to occur during the calendar year and ensure that representatives of the Ministry are given an opportunity to witness the survey.
Component leak survey – assessment and measurement of leaks
40 (1) A registered person shall ensure that a component leak survey required by subsection 39 (1) is performed in accordance with this section.
(2) Subject to subsection (3), each component that is part of a component leak survey required by subsection 39 (1) shall be assessed using one of the following methods:
- A portable gas detector shall be used to assess for a gaseous leak and to measure the concentration of VOCs discharged to air from a leaking component.
- An OGI instrument shall be used to assess for a gaseous leak.
- A fixed leak detection system shall be used to assess for a gaseous leak and to measure the concentration of VOCs discharged to air from a leaking component.
(3) Subject to subsection (4), at least one time in each 12-month period, a method set out in paragraph 1 or 3 of subsection (2) shall be used to assess and measure each component mentioned in subsection (2).
(4) Subsection (3) does not apply to a component that is identified in paragraph 7 of subsection 38 (3) as inaccessible.
(5) On and after January 1, 2023, each component that is part of a component leak survey required by subsection 39 (1) that may contain a liquid shall be assessed for a liquid leak using an audio or visual method to measure the leak rate of liquid discharged from each leaking component. The liquid leak rate shall be measured in number of drops per minute.
(6) A registered person shall ensure that a person who is required to perform a component leak survey receives training on the leak assessment methods mentioned in subsections (2) and (5) by a person with experience in the relevant method.
(7) No later than seven days after a leak is identified using an OGI instrument mentioned in paragraph 2 of subsection (2), the concentration of VOCs discharged to air from a leaking component shall be,
- measured using a portable gas detector; or
- determined using an accessory device to the OGI instrument.
(8) For the purpose of this industry standard, a determination made under clause (7) (b) is deemed to be a measurement of the concentration of VOCs discharged to air from a leaking component.
(9) The leak rate mentioned in subsection (5) shall be measured in accordance with the following rules:
- Observe the component for at least one minute and count the number of drops seen or heard.
- Repeat the observation required by paragraph 1 three times in a period of no more than ten minutes.
- Calculate the average of the leak rates observed under paragraphs 1 and 2.
Component leak survey plan
41. (1) A registered person shall ensure that a component leak survey plan that meets the requirements in this section is prepared prior to the initial component leak survey required by subsection 39 (1).
(2) A component leak survey plan shall be in electronic form and shall include the following information:
- A general description of the planned component leak survey including a description of,
- the components that are to be part of the component leak survey,
- the location of each component that will be part of the component leak survey,
- the method that will be used to assess each component for leaks in accordance with subsections 40 (2) and (5),
- the% by weight of benzene anticipated in leaks, based on the percentage of benzene by weight to which components in a process unit are exposed, and
- the training and experience of the individuals performing the component leak survey.
- If an OGI instrument will be used to perform the component leak survey, the number of view angles from which images will be taken for each component.
- A checklist of things to check or tasks to perform at the start of each day on which a component leak survey is performed, including,
- if a portable gas detector will be used to perform the component leak survey, determining and recording the calibration precision and the response time of the portable gas detector in accordance with Appendix 6-D,
- if an OGI instrument will be used to perform the component leak survey, confirmation that the date and time settings of the OGI instrument are correct, and
- if a fixed leak detection system will be used to perform any part of the component leak survey, an automated check for any malfunctioning sensors.
(3) No later than March 1 each year, the registered person shall update the component leak survey plan required by subsection (1) so that the information required in the plan is accurate for the surveys to be performed in the calendar year.
(4) If the information required in the component leak survey plan required by subsection (1) changes after March 1 of a year, the registered person shall ensure that the plan is updated so that it is accurate.
(5) If a change mentioned in subsection (4) affects the dates on which component leak surveys are anticipated to occur during the calendar year as set out under subsection 39 (6), the registered person shall ensure that the Director and a provincial officer are notified as soon as practicable of the change in dates.
Additional leak measurements - pumps, compressors and pressure relief devices
42. (1) Subject to subsection (2), a registered person shall ensure that a component required to be recorded under subsection 38 (1) is observed visually and audibly to identify gaseous and liquid leaks at least one time in every 12-hour period if,
- the date is on or after January 1, 2023; and
- the component is a pump, compressor or pressure relief device.
(2) Subsection (1) does not apply with respect to a component if the component was in benzene service for less than 300 hours in the previous calendar year and the registered person has made a record of the hours that the component was in benzene service in the previous calendar year including the dates and times that the component was in benzene service in the previous calendar year.
(3) The registered person shall ensure that the liquid leak rate from a leaking component is measured in accordance with the rules set out in subsection 40 (9) as soon as practicable after a liquid leak is identified under subsection (1).
(4) No later than seven days after a gaseous leak is identified under subsection (1), the registered person shall ensure that the concentration of VOCs discharged to air from a leaking component is measured using,
- a portable gas detector; or
- a fixed leak detection system.
Leaks - deviations and repair
43. (1) If the date is on or after January 1, 2018 and before January 1, 2020, and the concentration of VOCs discharged to air from a leaking component is greater than or equal to 1,000 ppm by volume, a registered person shall ensure that reasonable efforts are made to repair the component within a reasonable timeframe so that the concentration of VOCs discharged to air from the component is less than 1,000 ppm by volume.
(2) A registered person shall ensure that repairs are made in accordance with subsection (3) if one or more of the following criteria are met:
- A measurement required by this industry standard on or after January 1, 2020 indicates that the concentration of VOCs discharged to air from a leaking component is greater than or equal to 1,000 ppm by volume.
- A measurement required by this industry standard indicates that a component has a liquid leak rate of three drops per minute or greater.
(3) Subject to subsection (4) and section 44, the repairs required by subsection (2) include,
- no later than five days after taking a measurement mentioned in subsection (2), making all repairs to prevent, minimize or reduce the leak that can feasibly be made in the five-day period such as,
- if the component is a pump, tightening the packing gland nuts and ensuring that the seal flush is operating at design pressure and temperature, and
- if the component is a valve, tightening the bonnet bolts, replacing the bonnet bolts, tightening the packing gland nuts, and injecting a lubricant into lubricated packing;
- if the date is on or after January 1, 2020 and before January 1, 2023 and the measurement is in the range set out in Column 1 of Table 6-43, repairing the component within the repair period set out opposite the range in Column 2 of Table 6-43 so that the concentration of VOCs discharged to air from the component is less than the concentration set out opposite the repair period in Column 3 of Table 6-43; and
- if the date is on or after January 1, 2023 and the measurement is in the range set out in Column 1 of Table 6-43, repairing the component within the repair period set out opposite the range in Column 4 of Table 6-43 so that the liquid leak rate or concentration of VOCs discharged to air from the component is less than the leak rate or concentration set out opposite the repair period in Column 5 of Table 6-43.
(4) A component does not need to be repaired within the applicable repair period set out in clause (3) (b) or (c) if the component is taken out of service no later than the last day in the repair period set out in Column 2 or 4 of Table 6-43, as applicable.
(5) A registered person shall ensure that a component mentioned in subsection (4) is repaired so that concentration of VOCs discharged to air from the component is less than 1,000 ppm by volume before the component is put back into service.
Item | Column 1 Measurement Range |
Column 2 Repair Period (2020-2022) |
Column 3 Repair Range (2020-2022) |
Column 4 Repair Period (2023 and later) |
Column 5 Repair Range (2023 and later) |
---|---|---|---|---|---|
1 | 1,000 ppm – less than 10, 000 ppm of VOCs by volume | The 60-day period commencing the date the leak is measured. | Less than 1,000 ppm of VOCs by volume | The 30-day period commencing the date the leak is measured. | Less than 1,000 ppm of VOCs by volume |
2 | 10,000 ppm – 25,000 ppm of VOCs by volume | The 30-day period commencing the date the leak is measured. | Less than 10,000 ppm of VOCs by volume | The 15-day period commencing the date the leak is measured. | Less than 10,000 ppm of VOCs by volume |
3 | Greater than 25,000 ppm of VOCs by volume | The 15-day period commencing the date the leak is measured. | Less than 25,000 ppm of VOCs by volume | The 7-day period commencing the time the leak is measured. | Less than 25,000 ppm of VOCs by volume |
4. | Greater than three drops per minute | N/A | N/A | The 7-day period commencing the date the leak is measured. | 0 drops per minute |
Delay of repair list
44. (1) A component does not need to be repaired in accordance with the applicable repair period set out in section 43 if the sum determined under subsection (3) is less than 250,000 ppm by volume and one or more of the following criteria are met:
- The process unit in which the component is located must be shut down in order to repair the component.
- The component is a valve and the only repair that could be made to the valve without shutting down the process unit in which the valve is located is a drill and tap leak repair.
(2) The registered person shall ensure that the following information is recorded with respect to each component at a petroleum refining facility that is not repaired in accordance with the applicable repair period set out in section 43:
- The name of the component, the component identifier, and, if the component was installed after January 1, 2018, the serial number of the component.
- The process unit of which the component is part.
- The estimated fraction of benzene, by volume, that the component is exposed to.
- The reason that the component could not be repaired within the applicable repair period set out in section 43.
- The concentration of VOCs leaking from the component as measured under section 40 or 42.
- The calculated concentration of benzene leaking from the component, calculated as the product of the values set out in paragraphs 3 and 5.
- A description of any repairs made to the leaking component.
- The date and time of the next anticipated shut-down of the process unit of which the component is part.
(3) A registered person shall ensure the concentration of benzene recorded under paragraph 6 of subsection (2) is summed for each component recorded for the purpose of subsection (2) that is exposed to 50% or greater benzene, by weight.
(4) At least one time in each six-month period, a registered person shall ensure that a report that contains the following information is signed by the highest-ranking individual at the petroleum refining facility and submitted to a provincial officer:
- Each component set out in the record required by subsection (2).
- The length of time each component mention in paragraph 1 has been set out in the record required by subsection (2).
- For each component mention in paragraph 1, the concentration of benzene leaking from the component calculated in accordance with paragraph 6 of subsection (2).
- The sum determined under subsection (3).
- Each component that was set out in the previous report that is not set out in the report.
- For each component mentioned in paragraph 5, the results of the measurement required by section 45 following the repair to the component.
- A comparison of the number of components set out in the report to the number of components set out in the previous report.
- A comparison of the sum mentioned in paragraph 4 to the sum set out in the previous report.
(5) A registered person shall ensure that the next time a process unit is shut down, each component set out in the record required by subsection (2) that is part of the process unit is repaired so that the concentration of VOCs discharged to air from each component is less than 1,000 ppm by volume.
(6) Subject to subsection (7), if a component set out in the record required by subsection (2) is a valve, a registered person shall ensure that the next time the process unit in which the valve is located is shut down, the valve is replaced with a low emission valve or repacked with low emission valve packing that meets the criteria set out in subsection 46 (2).
(7) Subsection (6) does not apply with respect to a valve for which there is no low-emission replacement or low emission packing if the registered person notifies the Director, in writing, no later than 30 days after the date that the process unit in which the valve is located is shut down that there is no low-emission replacement or low emission packing for the valve.
(8) The notification required by subsection (7) shall include the following information:
- The date of the shut-down of the process unit in which the component is located.
- A description of the component.
- An explanation of why there is no low-emission replacement.
- A description of how the component was repaired instead of replaced.
(9) No later than six months after a component set out in the record required by subsection (2) is repaired, the registered person shall submit the following information, in writing, to a provincial officer:
- The date of the shut-down of the process unit in which the component is located.
- The date the component was repaired.
- A description of how the component was repaired.
- The concentration of VOCs leaking from the component after the repair was made.
(10) In this section,
- “drill and tap leak repair”
- means a method of repairing a leaking valve by drilling a hole into the valve packing gland, tapping the gland so that a small valve and fitting can be attached to the gland, and pumping new packing material into the gland.
Re-measurement following component repair or replacement
45. (1) After a component is required to be repaired in accordance with section 43 or 44 or replaced in accordance with section 46, a registered person shall ensure that the following measurements are made no later than the dates set out in subsection (2):
- One of the following methods is used to measure the concentration of VOCs discharged to air from the component that was required to be repaired or replaced,
- a portable gas detector, or
- a fixed leak detection system.
- The liquid leak rate from the component required to be repaired or replaced is measured in accordance with the rules set out in subsection 40 (9).
(2) The measurements required by subsection (1) shall be made,
- if the component is required to be repaired in accordance with subsection 43 (3), no later than the last day in the repair period set out in Column 2 or 4 of Table 6-43, as applicable;
- if the component is required to be repaired in accordance with subsection 43 (5), no later than seven days after the component is put back into service;
- if the component is required to be repaired in accordance with subsection 44 (5), no later than 30 days after the date that the process unit in which the component is located is placed back into service; and
- if the component is required to be replaced in accordance with section 46, no later than seven days after the component is replaced.
Component replacement
46. (1) A registered person shall ensure that a component required to be recorded under subsection 38 (1) is replaced with a new component if the component has been repaired two times in a 24-month period so that concentration of VOCs discharged to air from the component is less than 1,000 ppm by volume and is required by this industry standard to be repaired a third time in the period.
(2) Subject to subsection (3), if the component mentioned in subsection (1) is a valve, the valve shall be replaced with a low emission valve or repacked with low emission valve packing that meets the following criteria:
- The valve or valve packing has been tested by the manufacturer to determine the concentration of VOCs discharged from the valve or valve packing.
- The maximum concentration of VOCs determined under paragraph 1 shall not be greater than 500 ppm by volume.
- The average concentration determined under paragraph 1 shall not be greater than 100 ppm by volume.
(3) Subsection (2) does not apply with respect to a valve for which there is no low-emission replacement or low emission packing if the registered person notifies the Director, in writing, no later than 30 days after the date that the process unit in which the valve is located is shut down that there is no low-emission replacement or low emission packing for the valve.
(4) The notification required by subsection (3) shall include the following information:
- The date of the shut-down of the process unit in which the component is located.
- A description of the component.
- An explanation of why there is no low-emission replacement.
- A description of how the component was repaired instead of replaced.
(5) Subject to subsection (6), a registered person shall ensure that a component required to be replaced under subsection (1) is replaced with a new component no later than the last day in the repair period associated with the third repair mentioned in subsection (1) set out in Column 2 or 4 of the Table 6-43, as applicable.
(6) Subsection (5) does not apply to the replacement of a component if the component is taken out of service no later than the last day in the applicable replacement period set out in subsection (5).
(7) A registered person shall ensure that a component mentioned in subsection (6) is replaced before the component is put back into service.
Leaking components - annual calculations
47. (1) The combined annual percentage of leaking valves shall be calculated in accordance with the following formula:
AT ⁄ BT × 100
where,
- AT
- the total number of valves that required repair under sections 43 and 44 following each component leak survey required by subsection 39 (1) during a calendar year.
- BT
- the total number of valves assessed in each component leak survey required by subsection 39 (1) during a calendar year.
(2) The annual average concentration of VOCs from leaking components shall be calculated in accordance with the following formula:
XT ⁄ YT
where,
- XT
- the sum of the concentration, in ppm by volume, of VOCs discharged to air from each component following each component leak survey required by subsection 39 (1) during a calendar year.
- YT
- the total number of component for which a concentration was determined for XT.
(3) The percentage of leaking components shall be calculated in accordance with the following formula:
RT ⁄ CT × 100
where,
- RT
- the total number of components that require repair under sections 43 and 44.
- CT
- the total number of components assessed in the component leak survey required by subsection 39 (1).
Records - component leak survey
48. (1) A registered person shall ensure that for each component required to be listed in the electronic record required in subsection 38 (3) the following information is recorded in the electronic record with respect to each component leak survey required by subsection 39 (1):
- The date the component was assessed for leaks.
- The position title of the personnel who assigned an individual to assess the component for leaks and the date the individual received the training required by subsection 40 (6).
- The method used to assess the component for leaks, in accordance with section 40, including,
- if a portable gas detector or OGI instrument is used to assess the component, the unique identifier of the detector or instrument used,
- if a fixed leak detection system is used to assess the component, the distance from the component assessed by the fixed leak detection system to each sensor that assessed the component for leaks.
- If the component is not included in a component leak survey because the component was in benzene service for less than 300 hours in the previous calendar year, a notation that clause 39 (5) (a) applies and the dates and times during which the component was in benzene service in the previous calendar year.
- If the component is not included in a component leak survey because it was identified in subsection 38 (3) as inaccessible or unsafe, a notation that the component is identified as inaccessible or unsafe.
- The result of the assessment required by section 40, including, if a leak is identified,
- if the assessment indicated that VOCs were being discharged to air in a concentration of 1,000 ppm by volume or greater, the measured concentration of VOCs,
- if an OGI instrument was used to assess the component and the follow-up measurement required by subsection 40 (7) indicated that VOCs were being discharged to air in a concentration of 1,000 ppm by volume or greater,
- the method used to perform the follow-up measurement required by subsection 40 (7),
- a copy of the image or images produced by the OGI instrument,
- the time that an image mentioned in sub-subparagraph B was taken,
- the wind speed that is published by Environment and Climate Change Canada for the area in the vicinity of the facility on the date that the component was assessed for leaks,
- an indication of whether it was sunny or overcast at the time that the component was assessed for leaks, and
- if the assessment indicated that the component had a liquid leak rate of three drops per minute or greater, the measured liquid leak rate.
- If a concentration indicated in accordance with subparagraphs 6 i or ii is 1,000 ppm by volume or greater, the estimated mass emission rate of benzene, in grams per second, and a description of how the mass emission rate was estimated.
- A description of each action taken to repair the leak, including the date each action was taken.
- The position title of the personnel who assigned an individual to make the repair.
- The likely cause of the leak.
- The date that measurements required by subsection 45 (1) were made.
- The method used to make to take the measurements required by subsection 45 (1).
- The result of the measurements required by subsection 45 (1), including the concentration of VOCs or liquid leak rate measured, as applicable.
(2) After the completion of each component leak survey performed at a petroleum refining facility, a registered person shall ensure that a record of the following information is made:
- The start date and end date of the component leak survey.
- A summary of the methods used in the component leak survey.
- The percentage of leaking components, calculated in accordance with subsection 47 (3).
- An indication of whether the operating conditions at the petroleum refining facility were normal on each day of the component leak survey.
- If a fixed leak detection system was used for any part of the component leak survey, for each fixed leak detection system used,
- the number of sensors used to assess components for leaks,
- the manufacturer and model number of each sensor,
- the type of each analyzer linked to each sensor,
- the manufacturer and model number of each nalyzer,
- the year each sensor was installed,
- the year each analyzer was installed, and
- a record of any sensors that malfunctioned during the automated checks required by subparagraph 3 iii of subsection 41 (2).
- If a portable gas detector was used for any part of the component leak survey,
- the manufacturer and model number of each portable gas detector, and
- for each day on which part of a component leak survey was performed using a portable gas detector,
- the unique identifier of each portable gas detector used on the day,
- the concentration of calibration gas used to determine the calibration precision and the response time of each portable gas detector used on the day,
- the calibration precision and response time of each portable gas detector used on the day determined in accordance with Appendix 6-D, and
- if a portable gas detector used on the day uses flame ionization to detect VOCs and a calibration gas other than methane was used to determine the calibration precision and response time of the portable gas detector, the response factor used to adjust the portable gas detector in accordance with subsection 1 (3) of Appendix 6-D.
- If an OGI instrument was used for any part of the component leak survey, the manufacturer, model number and unique identifier of each OGI instrument.
Records – additional leak measurements
49. If a measurement required by section 42 identifies that the concentration of VOCs discharged to air from a leaking component is greater than or equal to 1,000 ppm by volume or that a component has a liquid leak rate of three drops per minute or greater, the registered person shall ensure that the following information is recorded with respect to the leaking component in the electronic record required in subsection 38 (3):
- The date and time the component was identified as leaking.
- The name of the individual who identified the component as leaking.
- The concentration of VOCs discharged to air from the component or liquid leak rate measured as required by subsection 42 (3) or (4).
- The date and time that the liquid leak rate or concentration of VOCs discharged to air from the component was measured.
- The name of the individual who measured the liquid leak rate or concentration of VOCs discharged to air from the component.
- The method used to measure the liquid leak rate or concentration of VOCs discharged to air from the component.
- If the concentration mentioned in paragraph 3 was measured using a portable gas detector,
- the unique identifier of the portable gas detector,
- the concentration of calibration gas used to determine the calibration precision and response time of the portable gas detector,
- the calibration precision and response time of the portable gas detector determined in accordance with Appendix 6-D.
- if the portable gas detector uses flame ionization to detect VOCs and a calibration gas other than methane was used to determine the calibration precision and response time of the portable gas detector, the response factor used to adjust the portable gas detector in accordance with subsection 1 (3) of Appendix 6-D.
- If the leak is a gaseous leak, the estimated mass emission rate of benzene, in grams per second, and a description of how the mass emission rate was estimated.
- A description of each action taken to repair the leak, including the date each action was taken.
- The position title of the personnel who assigned an individual to make the repair.
- The likely cause of the leak.
- The date that measurements required by subsection 45 (1) were made.
- The result of the measurements required by subsection 45 (1), including the concentration of VOCs or liquid leak rate measured, as applicable.
Part VII – Operation
Technology requirements – open-ended valves
50. A registered person shall ensure that each open-ended valve at the petroleum refining facility that is in benzene service is equipped with a cap, blind flange, plug, or a second valve that seals the open end.
Technology requirements – surge control vessels and bottoms receivers
51. (1) A registered person shall ensure that, on and after January 1, 2020, benzene from each of the following things at the petroleum refining facility is conveyed in a manner set out in section 4:
- A surge control vessel that is in benzene service.
- A bottoms receiver that is in benzene service.
(2) On and after January 1, 2020, for each surge control vessel and bottoms receiver mentioned in subsection (1), a registered person shall ensure that a written description is made that sets out how and to where the benzene is conveyed.
Operating parameter summary table
52. (1) Subject to subsections (2), (3) and (5), on and after January 1, 2018, a registered person shall ensure that a table labelled “Operating Parameter Summary Table” is prepared that reproduces Table 6-52 in a manner that includes each method listed in Column 1 of Table 6-52 that is at the petroleum refining facility and that is associated with a registered contaminant.
(2) A registered person who is required under subsection (1) to reproduce Item 4 of Table 6-52 in the Operating Parameter Summary Table does not have to set out the information in Columns 3 to 6 of Item 4 of Table 6-52 if the person sets out the information in the following manner:
- Column 3: Concentration of VOCs (ppm)
- Column 4: Outlet
- Column 5: One time in each 24-month period
- Column 6: --
(3) Where Table 6-52 refers to an operating parameter, location, or frequency that is to be consistent with a recommendation made by a professional, the recommendation and the source of the recommendation shall be set out in the Operating Parameter Summary Table.
(4) The source of the professional recommendation mentioned in subsection (3) shall be one of the following:
- An operating and maintenance manual provided by a manufacturer of the thing for which the recommendation is being given.
- Written instructions provided by a supplier of the thing for which the recommendation is being given.
- A letter from a manufacturer mentioned in paragraph 1 or supplier mentioned in paragraph 2, setting out the recommendation.
- A letter from a professional engineer setting out the recommendation, the rationale for the recommendation and a description of the relevant experience with respect to the recommendation being made. The engineer must have relevant experience with respect to the recommendation being made.
(5) The Director may order a registered person to do one or more of the following:
- Include information in Columns 3 to 6 of the Operating Parameter Summary Table if the Director is of the opinion that the information is necessary to ensure the normal operation of the method.
- Remove information from Columns 3 to 6 of the Operating Parameter Summary Table if the Director is of the opinion that the information is not appropriate to ensure the normal operation of the method.
(6) No later than 30 days after a change is made at the petroleum refining facility that would affect the information in the Operating Parameter Summary Table, the Table shall be updated to reflect the change.
Item | Column 1 Method |
Column 2 Equipment Associated with the Method |
Column 3 Operating Parameter |
Column 4 Measurement Location |
Column 5 Measurement Frequency |
Column 6 Calculated Parameter |
---|---|---|---|---|---|---|
1. | Flare | Equipment | Pilot Flame On or Off | Pilot Flame | Continuously when a substance is being conveyed to the flare | -- |
2. | Thermal Oxidizer | Equipment | Temperature | At the point that represents a residence time of 0.75 seconds | Continuously | -- |
3. | Catalytic Oxidizer | Equipment | Temperature | A location consistent with a professional recommendation | Continuously | -- |
4. | Air pollution control device required by paragraph 2 of subsection 4 (1) other than a thermal oxidizer or a catalytic oxidizer | Equipment | Concentration of benzene |
|
One time in each 24-month period | % removal of benzene = [1 − (Coutlet ⁄ Cinlet)] |
5. | A method required by: section 56 | Equipment | One or more operating parameters consistent with a professional recommendation | A location consistent with a professional recommendation | A frequency consistent with a professional recommendation | -- |
Measurement of operating parameters
53. (1) A registered person shall ensure that each operating parameter set out in Column 3 of the Operating Parameter Summary Table required by section 52 is measured at least as often as the frequency required to be set out in Column 5 of the Table at the location required to be set out in Column 4 of the Table.
(2) The results of the measurements required by subsection (1) shall be used to determine the calculated parameter in Column 6 of the Operating Parameter Summary Table required by section 52.
(3) The measurements required by subsection (1) for Item 4 of Table 6-52 shall be taken in accordance with a plan that, in the opinion of the Director, is adequate to result in the effective measurement of the operating parameter mentioned in subsection (1).
(4) Each time a measurement is required to be taken by subsection (1) for Item 4 of Table 6-52, the registered person shall ensure that,
- written notice is provided to the Director at least 15 days before the measurement is taken;
- an opportunity is provided for representatives of the Ministry to witness the taking of the measurement; and
- no later than four months after the measurements are taken, the results of the measurements are submitted to the Director and a provincial officer.
(5) Measurements required by subsection (1) with respect to Item 1 of Table 6-52 shall be taken using one or more of the following technologies:
- A thermocouple.
- An optical system that uses ultraviolet or infrared technology.
- Flame ionization.
- An acoustic system.
(6) A registered person shall ensure that an instrument used to measure an operating parameter for the purpose of this industry standard is calibrated in accordance with a recommendation made by a professional. The source of the recommendation shall be one of the sources set out in subsection 52 (4).
(7) A registered person shall ensure that the following information is recorded:
- Each measurement required to be taken under subsection (1).
- Each calculation required to be made under subsection (2).
- The date on which the measurement in paragraph 1 was taken and the calculation in paragraph 2 was made.
Phase-in for new air pollution control devices
54. Sections 52 and 53 do not apply in respect of an air pollution control device at a petroleum refining facility for a period of six months after the installation of the device if the device is installed after the date on which the petroleum refining facility is first registered with respect to this industry standard.
Part VIII – Requirement To Continue The Use Of Methods To Manage Emissions
Identifying managed sources
55. (1) A registered person shall ensure that a table is prepared in accordance with this section and updated in accordance with section 57.
(2) The table required by subsection (1) shall contain the following information:
- Column 1: Each piece of equipment at the petroleum refining facility from which the discharge of a registered contaminant is prevented, minimized or reduced by a method mentioned in subsection (3).
- Column 2: Opposite each piece of equipment required to be set out by paragraph 1, each method mentioned in subsection (3) that prevents, minimizes or reduces the discharge of a registered contaminant from the piece of equipment.
(3) A method mentioned in subsection (2) includes a method such as,
- the use of an air pollution control device;
- the selection and use of equipment that more effectively prevents, minimizes or reduces the discharge of a registered contaminant than the selection or use of other equipment;
- the operation of a process in a manner that prevents, minimizes or reduces the discharge of a registered contaminant into the air from one or more sources of contaminant;
- the design, installation and operation of a stack in a manner that increases the dispersion of a registered contaminant; and
- the use of material to prevent, minimize or reduce the discharge of a registered contaminant to the air, for example material substitution.
(4) If a method mentioned in subsection (2) is the selection of equipment in accordance with clause (3) (b), the equipment shall be listed as the method in Column 2 of the table required by subsection (1) and as the equipment in Column 1 of the table.
Requirement to continue the management of sources
56. A registered person shall not operate or cause or permit the operation of equipment set out in the table required by section 55 unless the discharge of registered contaminants from the equipment is prevented, minimized or reduced by a method that is at least as effective at preventing, minimizing or reducing the discharge into the air as the associated method required to be listed opposite the equipment in Column 2 of the table.
Changes to managed sources
57. (1) No later than 30 days after any of the following changes occur at a petroleum refining facility, the table required by section 55 shall, having regard to subsection (2), be updated in accordance with the following rules:
- If a method to prevent, minimize or reduce the discharge of a registered contaminant is added or replaced at the petroleum refining facility, the table shall be updated to reflect the change.
- If a piece of equipment that may discharge, or from which may be discharged, a registered contaminant is added or replaced at the petroleum refining facility, the table shall be updated to reflect the change.
- If a piece of equipment set out in the table is removed from the petroleum refining facility, the piece of equipment shall be removed from the table.
- If all equipment associated with a method set out in the table has been removed from the table, the method shall be removed from the table.
- If a notice given under subsection (4) indicates that a method is no longer necessary, the method shall be removed from the table.
- If the table is updated in accordance with paragraph 5 such that no method is set out opposite a piece of equipment in the table, the piece of equipment shall be removed from the table.
(2) Subject to subsections (3) and (4), a change mentioned in subsection (1) shall not be made unless the following criteria are met:
- A change that adds, replaces or otherwise alters a method shall add, replace or alter the method in a manner that is at least as effective at preventing, minimizing or reducing the discharge of registered contaminants as the method that was listed in the table immediately prior to the change.
- A change that adds a piece of equipment that is similar to a piece of equipment required to be set out in the table shall only be made if Column 2 of the table contains a method that is at least as effective at preventing, minimizing or reducing the discharge of registered contaminants as the most effective method associated with a similar piece of equipment.
(3) Subsection (2) does not apply if the change is required by a section of this industry standard, other than this section.
(4) The Director may, upon request, give a registered person written notice indicating that a change that does not meet the requirements mentioned in subsection (2) may be made, in accordance with the notice, if the Director is of the opinion that at least one of the following statements is true:
- The method that is the subject of the request is comparable to the effectiveness of the method that would be required by subsection (2).
- Any adverse effect would likely not be better prevented, eliminated or ameliorated if a method required by subsection (2) were used.
- No adverse effect is likely to occur.
- The registered contaminants affected by the change are discharged in an amount that is negligible.
(5) A request that is made in respect of subsection (4) shall be made by a registered person and shall include the following information:
- A rationale for the request.
- Each piece of equipment associated with the method that is the subject of the request.
(6) Before the Director gives a person a notice under subsection (4), the Director shall give the person a draft of the notice and an opportunity to make written submissions to the Director during the period that ends 30 days after the draft is given.
Specified source management
58. The Director may order a registered person to use a method if,
- a change was made to a method that, in the opinion of the Director, does not meet the criteria set out in subsection 57 (2); or
- a piece of equipment is, or was previously, listed in the table required by section 55, and the Director is of the opinion that discharges from the equipment may cause an adverse effect.
Notification of changes to management of sources
59. (1) Subject to subsection (2), no later than 30 days after a change mentioned in section 57 or 58 is made at a petroleum refining facility, the registered person shall ensure that a provincial officer is notified in writing of the change.
(2) Subsection (1) does not apply if the thing affected by the change is a thing which may discharge or from which may be discharged a registered contaminant in an amount that is negligible.
(3) The notification required by subsection (1) shall include the following information:
- A description of the change, including a description of the equipment and methods affected by the change and the date that the change was made.
- One of the following with respect to the change mentioned in paragraph 1:
- An explanation of how the change meets the criteria set out in subsection 57 (2).
- If the change was authorized by a notice given under subsection 57 (4), the reference number of the notice.
- If the change was required by an order given under section 58, the reference number of the order.
Part IX – Ambient Monitoring
Ambient monitoring - benzene
60. (1) On and after January 1, 2018, a registered person shall ensure that the concentration of benzene discharged from the petroleum refining facility into the air is measured by,
- at least 12 ambient monitors, if the petroleum refining facility is on a property that is 80 hectares or greater; or
- at least six ambient monitors, if the petroleum refining facility is on a property that is less than 80 hectares.
(2) Each monitor required by subsection (1) shall,
- sample the air continuously over a two-week period;
- be, in the opinion of the Director, adequate to effectively measure the concentration of benzene in the air; and
- be, in the opinion of the Director, located in a manner that adequately reflects the benzene discharged from the petroleum refining facility.
(3) In forming the opinion required under clause (2) (b), the Director shall have regard to,
- the type of monitor;
- the make and model of the monitor;
- the frequency of measurement of the monitor; and
- the sampling and analytical protocols to be used with the monitor.
(4) In forming the opinion required under clause (2) (c), the Director shall have regard to,
- the property boundary of the petroleum refining facility;
- the wind rose or predominant wind direction at the petroleum refining facility;
- the location and height of the sources of contaminant that discharge benzene to the air at the petroleum refining facility, including,
- storage vessels,
- product loading areas, and
- sewage treatment;
- the presence of any of the following places near the petroleum refining facility,
- a health care facility,
- a senior citizens’ residence or long-term care facility,
- a child care facility,
- an educational facility, and
- a dwelling;
- whether a local First Nation may be interested in the location of the monitors; and
- the location of the other monitors required by subsection (1).
(5) A registered person shall ensure that the air sampled over a two-week period by a monitor required by subsection (1) is analysed in a laboratory as soon as reasonably possible to determine the concentration of benzene in micrograms per cubic metre.
(6) A registered person shall ensure that the following information is recorded for each monitor:
- The location of the monitor.
- Each measured concentration of benzene mentioned in subsection (5).
- For each value mentioned in paragraph 2, the dates of the period of time during which the monitor sampled air.
Benzene measurements baseline
61. (1) A registered person shall ensure that a baseline for benzene at a petroleum refining facility is determined in accordance with this section.
(2) No later than March 31 in the year following the first full three calendar years in which this section applies in respect of the petroleum refining facility mentioned in subsection (1), a baseline shall be determined by performing the following steps with respect to each ambient monitor required by subsection 60 (1):
- For each two-week period in the previous three calendar years record one of the following,
- if the monitor indicates a measurement of a concentration of benzene, record the measured concentration of benzene,
- if the monitor indicates that the measurement of the concentration of benzene was below the detection limit of the monitor, record half of the detection limit of the monitor as the concentration of benzene, or
- if the monitor provides no indication of any measurements with respect to the concentration of benzene, do not record a concentration but instead record an explanation of why no measurement of benzene was taken.
- Translate each concentration recorded in paragraph 1 to its equivalent natural logarithm.
- Calculate the mean of all of the values translated in paragraph 2.
- Calculate the square of the standard deviation of all of the values translated in paragraph 2 using the following equation:
Where,
- S
- is the standard deviation;
- m
- is the number of two-week average concentrations recorded in paragraph 1;
- xi
- is each value translated in paragraph 2;
- X
- is the value calculated in paragraph 3.
(3) Subject to subsection (4), no later than March 31 in each year following the fourth full calendar year after this section applies in respect of the petroleum refining facility, the baseline mentioned in subsection (1) shall be re-determined by performing the steps set out in subsection (2) using concentrations of benzene measured by the monitor in the previous three calendar years.
(4) Subsection (3) does not apply if the concentration of benzene measured by the monitor averaged over the calendar year mentioned in subsection (3) is higher than,
- if no re-determination has previously been made under subsection (3), the baseline determined under subsection (2); or
- if a re-determination has previously been made under subsection (3), the most recent re-determination under subsection (3).
(5) The results of each step required to be performed under subsections (2) and (3) shall be recorded.
Statistical analysis of benzene measurements
62. (1) For the purpose of this section, reference to a statistically significant increase in the concentration of benzene is a reference to the determination of whether the concentration of benzene measured at a monitor during a calendar year is higher than the concentration of benzene measured at the monitor during the three-year period in which the most recent baseline was determined under section 61 and, if so, whether the increase in concentration is statistically significant.
(2) A registered person shall ensure that a determination of whether a statistically significant increase in the concentration of benzene has occurred in a year is made in accordance with this section.
(3) No later than March 31 in each year following the fourth full calendar year in which this section applies in respect of a petroleum refining facility, a statistical analysis shall be completed by performing the following steps with respect to each ambient monitor identified as adequate under section 60:
- For each two-week period in the previous calendar year record one of the following,
- if the monitor indicates a measurement of a concentration of benzene, record the measured concentration of benzene,
- if the monitor indicates that the measurement of the concentration of benzene was below the detection limit of the monitor, record half of the detection limit of the monitor as the concentration of benzene, or
- if the monitor provides no indication of any measurements with respect to the concentration of benzene, do not record a concentration but instead record an explanation of why no measurement of benzene was taken.
- Translate each two-week average recorded in paragraph 1 to its equivalent natural logarithm.
- Calculate the mean of all of the values translated in paragraph 2.
- Calculate the square of the standard deviation of all of the values translated in paragraph 2 using the following equation:
Where,
- S
- is the standard deviation;
- n
- is the number of two-week average concentrations recorded in paragraph 1;
- xi
- is each value translated in paragraph 2;
- X
- is the value calculated in paragraph 3.
- Calculate the test statistic using the following equation:
Where,
- T
- is the test statistic;
- Y
- is the value calculated in paragraph 3;
- X
- is the most recent value calculated in paragraph 3 of subsection 61 (2);
- S1
- is the most recent value calculated in paragraph 4 of subsection 61 (2);
- S2
- is the value calculated in paragraph 4;
- m
- is the most recent number of two-week average concentrations recorded in paragraph 1 of subsection 61 (2);
- n
- is the number of two-week average concentrations recorded in paragraph 1.
- Calculate the degrees of freedom using the following equation:
Where,
- (v)
- is the degrees of freedom;
- S1, S2, m and n
- have the same meanings as set out in paragraph 5.
- Find the value calculated in paragraph 6 in Column 1 of Table 6-62 and determine the value set out opposite that value in Column 2.
- Determine whether there has been a statistically significant increase in the concentration of benzene at the monitor by assessing whether the value calculated in paragraph 5 exceeds the value determined under paragraph 7.
(4) A registered person shall ensure that the following information is recorded for each monitor:
- The results of each step performed for the purpose of this section.
- Any changes to the baseline for the monitor in accordance with section 61.
Item | Column 1 Degrees of Freedom (v) |
Column 2 Test Statistic (T) with level of significance (%) = 0.0005 |
---|---|---|
1. | 1 | 636.6 |
2. | 2 | 31.60 |
3. | 3 | 12.92 |
4. | 4 | 8.610 |
5. | 5 | 6.869 |
6. | 6 | 5.959 |
7. | 7 | 5.408 |
8. | 8 | 5.041 |
9. | 9 | 4.781 |
10. | 10 | 4.587 |
11. | 11 | 4.437 |
12. | 12 | 4.318 |
13. | 13 | 4.221 |
14. | 14 | 4.141 |
15. | 15 | 4.073 |
16. | 16 | 4.015 |
17. | 17 | 3.965 |
18. | 18 | 3.922 |
19. | 19 | 3.883 |
20. | 20 | 3.850 |
21. | 21 | 3.819 |
22. | 22 | 3.792 |
23. | 23 | 3.768 |
24. | 24 | 3.745 |
25. | 25 | 3.725 |
26. | 26 | 3.707 |
27. | 27 | 3.690 |
28. | 28 | 3.674 |
29. | 29 | 3.659 |
30. | 30 | 3.646 |
31. | 40 | 3.551 |
32. | 60 | 3.460 |
33. | 120 | 3.373 |
34. | ∞ | 3.291 |
Notification – ambient monitoring
63. (1) A registered person shall ensure that, as soon as practicable, a provincial officer is notified in writing if it is determined under section 62 that there has been a statistically significant increase in the concentration of benzene at an ambient monitor required by subsection 60 (1).
(2) No later than six months after notice is required to be given under subsection (1), the registered person shall ensure that the following information is submitted, in writing, to a provincial officer:
- The measured and calculated values relating to the statistically significant increase in the concentration of benzene.
- An explanation of the suspected cause of the statistically significant increase in the concentration of benzene.
- A description of any steps taken or that will be taken to prevent, minimize, or reduce the risk of future statistically significant increases in the concentration of benzene, if any.
- An indication of the date by which each step mentioned in paragraph 3 will be implemented.
- A written explanation of how each step mentioned in paragraph 3 will prevent, minimize or reduce the risk of any future statistically significant increases in the concentration of benzene.
Part X – Complaints, Records and Reporting
Complaints procedure
64. (1) A registered person shall ensure that the following steps are taken to properly respond to each complaint that relates to a matter addressed in this industry standard:
- A prompt response is made to the person who made the complaint, unless the person requests that a response not be made or fails to provide contact information.
- Action is taken to remedy the cause of the complaint.
- A written record of the complaint is prepared that includes the following information:
- A description of the complaint.
- The date and time that the complaint was received.
- If the complaint relates to a discharge of a contaminant to air, the date, time and suspected cause of the complaint, including whether any activities at the facility may have given rise to the complaint.
- If the complaint relates to a discharge of a contaminant to air, ambient temperature at the time of the discharge to which the complaint relates.
- If the complaint relates to a discharge of a contaminant to air, the approximate wind direction and wind speed at the time of the discharge to which the complaint relates.
- If the complaint relates to a discharge of a contaminant to air, the general weather conditions at the time of the discharge to which the complaint relates.
- A description of any actions taken to address the matter to which the complaint relates and the date each action was completed.
- A description of any actions taken to prevent a similar future complaint and the date each action was completed.
(2) If a complaint mentioned in subsection (1) relates to the discharge of a contaminant to air from the petroleum refining facility, the registered person shall ensure that the Ministry’s Spills Action Centre is notified of the complaint as soon as practicable after the complaint is made.
(3) No later than five days after notification is required to be given under subsection (2), the registered person shall ensure that the record mentioned in paragraph 3 of subsection (1) is submitted to a provincial officer.
Annual summary reports
65. (1) On and after January 1, 2019, a registered person shall ensure that annual summaries are prepared and reviewed in accordance with this section.
(2) No later than March 31 each year, the following summaries shall be prepared and the information therein shall pertain to the preceding calendar year:
- A table, labelled “Implementation Summary Table”, that, for the calendar year, sets out,
- A summary of the provisions of this industry standard that apply to the petroleum refining facility, in accordance with section 2.
- For each provision mentioned in subparagraph i,
- an indication of the date on which the provision applies to the petroleum refining facility, and
- if compliance with the provision has been achieved, an indication of the date on which compliance was achieved.
- A report entitled “Annual Summary of Component Leak Detection and Repairs” that sets out,
- the number of component leak surveys conducted during the calendar year at the petroleum refining facility in accordance with subsection 39 (1),
- the start date and end date of each component leak survey conducted at the petroleum refining facility during the calendar year,
- if less than three component leak surveys were conducted during the calendar year,
- the combined annual percentage of leaking valves during the previous calendar year, calculated in accordance with subsection 47 (1), and
- the annual average concentration of VOCs from leaking components during the previous calendar year, calculated in accordance with subsection 47 (2),
- for each process unit at the petroleum refining facility that contains one or more components required to be recorded under subsection 38 (1), the following information:
- The name and a description of the process unit.
- Each date on which the process unit did not operate and the duration for which it did not operate.
- The total number of components in the process unit.
- The number of inaccessible components and number of components that have been identified as unsafe components in the process unit.
- The start date and end date of each component leak survey during the calendar year that assessed a component in the process unit.
- The number of components in the process unit that were surveyed in the calendar year and the method used to assess each component.
- The number of components, expressed as a percentage of the total components in the process unit,that had leaks at the following concentrations:
- Greater than 0 and less than or equal to 1,000 ppm of VOCs by volume.
- Greater than 1,000 ppm and less than or equal to 5,000 ppm of VOCs by volume.
- Greater than 5,000 ppm and less than or equal to 10,000 ppm of VOCs by volume.
- Greater than 10,000 ppm and less than or equal to 25,000 ppm of VOCs by volume.
- Greater than 25,000 ppm of VOCs by volume.
- A summary, by component type, of the repairs to components made during the calendar year, including the shortest, longest and average time between detecting a leak and repairing the component so that the concentration of VOCs discharged to air from the component was less than 1,000 ppm by volume.
- A summary, by component type, of the number of repairs to components in the process unit each calendar year for the shorter of,
- the previous 10 calendar years, and
- the calendar years since the date the petroleum refining facility was first registered to this industry standard.
- The number of components in the process unit, expressed as a percentage of the total components in the process unit, that have been repaired more than one time in the calendar year so that the concentration of VOCs discharged to air from the component is less than 1,000 ppm by volume.
- The number of valves replaced with low-emission valves and the number of valves replaced with low emission valve packing during the calendar year, and an indication of how many of the valves were required by subsection 44 (6) and section 46 to be replaced.
- The most recent report mentioned in subsection 44 (4) for the petroleum refining facility.
- A report entitled “Annual Summary of Defects and Repairs for Storage Vessels” that sets out, for each storage vessel identified on the list required by subsection 9 (3),
- a summary of the information required by subsection 20 (2), paragraphs 5 to 7 of section 22, and subsection 23 (2),
- an indication of any changes in the number of defects or repairs from the summary of the previous year,
- the number of times an event that caused one or more defects occurred at the facility during the calendar year,
- an indication of whether any of the events mentioned in subparagraph iii were of particular concern,
- an indication of whether the number of events mentioned in subparagraph iii suggest a recurring issue, both in respect of the calendar year and in respect of previous calendar years, and
- an explanation of any actions taken to address the events mentioned in subparagraph iii.
- A report entitled “Annual Summary of Air Emissions from Industrial Sewage Systems” that sets out,
- for each primary oil-water separator at the petroleum refining facility, a summary of the information required by paragraph 2 or 3 of subsection 30 (1), paragraphs 5 to 8 of section 31 and subsection 32 (2), and
- a summary of the information required by subparagraph 2 ii of section 34.
- A report entitled “Annual Benzene-containing Product Loading Report” that sets out a summary of the information required by subsection 35 (1), if any.
- A report entitled “Annual Ambient Monitoring Report for Petroleum Refining – Industry Standard” that sets out,
- a map showing the location of each monitor required by subsection 60 (1), the information required by clause 60 (4) (d), and other topographical information including any nearby water bodies, roadways and adjacent land uses,
- for each monitor required by subsection 60 (1),
- the information required by subsection 60 (6),
- the results of calculations required by section 62 to identify whether a statistically significant increase in the concentration of benzene occurred,
- a summary showing the annual average benzene concentration results from the time that the monitor was first required by subsection 60 (1),
- a summary of the information required by section 63.
- A summary that, for the calendar year, sets out changes made to the Operating Parameter Summary Table and summarizes the information that was required to be updated in accordance with subsection 52 (6).
- A table labelled “Performance Summary Table” that, for the calendar year, sets out,
- a summary of all notifications required to be given under subsections 8 (1),
- a summary of the number of contraventions of subsections 11 (1) and 26 (1), and
- an indication of whether an order has been given to the petroleum refining facility under subsection 52 (5) or section 58.
- A table labelled “Annual Summary of Changes to Source Information” that, for the calendar year, sets out the table required by section 55 with an additional column setting out, for each piece of equipment, an indication if the information in columns 1 or 2 has changed from information set out in the previous calendar year. If no changes have occurred in the calendar year, the words “no change” shall be set out in the additional column.
- A table labelled “Complaint Summary Table” that sets out the total number of complaints described in section 64 that have been received by the petroleum refining facility in the calendar year and compares the number to the number of complaints received by the petroleum refining facility in the previous calendar year.
(3) No later than March 31 each year, the highest-ranking individual at the petroleum refining facility shall certify in writing that the summaries required by paragraphs 1 to 10 of subsection (2) have been prepared in accordance with this industry standard and that the information contained in the summaries is,
- accurate and complete; and
- true to the best of his or her knowledge.
(4) The summary tables required by paragraphs 1 and 8 of subsection (2) shall be,
- made available for examination by any person, without charge, by ensuring it is posted and available on the website for the petroleum refining facility and by making it available during regular business hours at the place to which the summaries relate; and
- given, without charge, to any person within 15 days after the person requests it.
Public reporting – ambient monitoring
66. (1) On and after January 1, 2018, a registered person shall ensure that the following information is made available for examination by any person, without charge, by ensuring it is posted and available on a website for the petroleum refining facility and by making it available during regular business hours at the place to which the information relates:
- A map showing the location of each monitor required by subsection 60 (1), the information required by clause 60 (4) (d) and other relevant topographical information including any nearby water bodies, roadways and adjacent land uses.
- A table showing the information required by subsection 60 (6) for each monitor for the calendar year, updated in accordance with subsection (2) and set out in a manner that can be understood by persons without specialized scientific training.
- A copy of the report mentioned in paragraph 6 of subsection 65 (2).
(2) No later than 60 days after a two-week air sample is taken by a monitor required by subsection 60 (1), the information required by subsection 60 (6) shall be added to the table mentioned in paragraph 2 of subsection (1).
Records
67. (1) Subject to subsection (2), a registered person shall ensure that each record required by this industry standard is,
- retained at the petroleum refining facility for at least five years; and
- if applicable, maintained on the website for the petroleum refining facility for at least five years.
(2) A registered person shall ensure that each record mentioned in section 66 is retained at the petroleum refining facility and maintained on the website for the petroleum refining facility for at least 10 years.
(3) A person required to make a record available under subsections (1) or (2) shall make the record available,
- to a provincial officer or Director upon request as soon as practicable; and
- in a form approved by the Director, including, if required by the Director, an electronic format specified by the Director.
(4) In addition to the records mentioned in subsection (1), a registered person shall ensure that each document relating to the recommendations of the manufacturer for each device at the petroleum refining facility with respect to the use, operation and maintenance of the device is retained for the period during which the device is used or operated.
(5) In addition to the records mentioned in subsection (1), if a component is, in the opinion of the highest ranking individual at a petroleum refining facility, an unsafe component, the registered person shall ensure that each document relating to the opinion of the highest ranking individual is retained at the petroleum refining facility for the period during which the component is in benzene service.
Part XI – 2020 Emergency Management
Requirements, 2020
68. (1) For the calendar year 2020, the requirement in clause 39(2)(a) is deemed to require a component leak survey at least two times during the calendar year instead of three and is deemed to require completion of at least one component leak survey during each of the following periods,
- the period starting July 1, 2020 and ending September 30, 2020 and
- the period starting October 1, 2020 and ending December 31, 2020.
(2) Subsection (3) applies if as of March 16, 2020 a registered person last used the method set out in paragraph 1 or 3 of subsection 40 (2) to assess a component mentioned in subsection 40 (2) for leaks during a component leak survey conducted in the period starting April 1, 2019 and ending June 30, 2019.
(3) Despite subsection 40 (3), in the circumstances referred to in subsection (2), the registered person is not required to assess the component using a method set out in paragraph 1 or 3 of subsection 40 (2) within 12 months and instead the registered person shall assess the component using a method set out in paragraph 1 or 3 of subsection 40 (2) in the calendar year 2020.
(4) For the purposes of determining a four-month period referred to in subsections 17 (2) and 28 (1), the time period from March 16, 2020 to July 16, 2020 shall be excluded.
Appendix 6
Item | Column 1 CAS No. |
Column 2 Contaminant |
---|---|---|
1 | 71-43-2 | Benzene |
2 | 50-32-8 | Benzo(a)pyrene |
Item | Column 1 CAS No. |
Column 2 Contaminant |
---|---|---|
1 | 71-43-2 | Benzene |
Item | Column 1 CAS No. |
Column 2 Contaminant |
---|---|---|
1 | 50-32-8 | Benzo(a)pyrene |
Appendix 6-D: Portable Gas Detector - Methodology and Instrumentation
Definitions
1. (1) For the purpose of this Appendix 6-D,
- “calibration gas”
- means a VOC used to adjust an instrument reading to a known value;
- “calibration precision”
- means the degree of agreement between a known concentration and an instrument’s measurements of a known concentration;
- “cylinder calibration gas”
- means a calibration gas that is packaged in a cylinder;
- “component interface”
- means the surface of a component where a leak may occur;
- “response factor”
- means the ratio of the known concentration of a VOC to an instrument’s measurements of a known concentration;
- “response time”
- means the time from introducing a VOC to an instrument to the time at which 90% of the corresponding final value is reached as displayed on the instrument readout;
- “zero gas”
- means a gas containing less than 10 ppmv VOCs that is used for the calibrating the zero point of an instrument.
(2) For the purposes of the procedures set out in this Appendix, the calibration gas used shall be,
- if the portable gas detector uses flame ionization to detect VOCs, methane; and
- if the portable gas detector uses photoionization technologies, isobutylene gas of a concentration that is between 900 ppm and 1,100 ppm by volume.
(3) Despite clause (2) (a), a calibration gas used with a portable gas detector that uses flame ionization may be a VOC other than methane if,
- the VOC has a published response factor; and
- the portable gas detector has been adjusted, using the response factor, to display a concentration that is the methane-equivalent concentration of the VOC.
(4) For the purposes of subsections 2 (3) and (4), the calibration gas used with a portable gas detector that uses flame ionization to detect VOCs shall have a methane or methane equivalent concentration that is between 900 ppm and 1,100 ppm by volume.
VOCs Leak Measurement - Instrument Requirements
2. (1) As required by clause 3 (a) of this industry standard, a portable gas detector shall meet the following criteria:
- The portable gas detector shall be designed to detect VOCs. The portable gas detector shall use flame ionization or photoionization technologies to detect VOCs.
- The portable gas detector shall be capable of measuring concentrations of VOCs that are as low as 100 parts per million by volume.
- The portable gas detector shall be capable of measuring and displaying to at least ±2.5% of 100 parts per million by volume.
- The probe of the portable gas detector shall be fitted with a glass wool plug or filter to prevent plugging of the portable gas detector.
- The portable gas detector shall be equipped with an electrically-driven pump to ensure that a sample is provided to the detector at a constant flow rate. The nominal sample flow rate, as measured at the sample probe tip, shall be between 0.20 and 2.0 litres per minute.
- The portable gas detector shall be equipped with a probe, probe extension or sampling system not to exceed 6.4 mm (¼inch) in outside diameter, with a single end opening for admission of sample.
- The portable gas detector shall be intrinsically safe for operation in explosive airs.
- The response factor of the portable gas detector shall be less than 10.
- The calibration precision of the portable gas detector, determined in accordance with subsection (3), shall be equal to or less than 10% of the calibration gas value.
- The response time of the portable gas detector, determined in accordance with subsection (4), shall be equal to or less than 10 seconds.
(2) A portable gas detector shall be calibrated using a zero gas and a calibration gas and if the portable gas detector uses flame ionization to detect VOCs it shall be calibrated.
- if the portable gas detector is not capable of multi-point calibration, by single point calibration using a calibration gas that has a methane or methane equivalent concentration of between 900 ppm and 1,100 ppm by volume; or
-
if the portable gas detector is capable of multi-point calibration, by multi-point calibration using,
- for the lowest span, a calibration gas that has a methane or methane equivalent concentration of between 900 ppm and 1,100 ppm by volume; and
- for the highest span, a calibration gas that has a methane or methane equivalent concentration of between 9,000 and 11,000 ppm by volume.
(3) The calibration precision shall be determined by taking the following steps:
- Introduce a calibration gas to the probe of the portable gas detector and record the observed instrument reading.
- Introduce a zero gas to the probe of the portable gas detector until a stable reading is obtained.
- Repeat the steps set out in paragraphs 1 and 2 two more times for a total of three repetitions.
- Calculate the average algebraic difference between the three instrument readings taken under paragraph 1 and the known concentration of the calibration gas.
- Divide the average difference mentioned in paragraph 4 by the known concentration of the calibration gas mixture and multiply the result by 100.
(4) The portable gas detector response time shall be determined by taking the following steps:
- Introduce zero gas to the probe of the portable gas detector.
- When the instrument reading for the zero gas has stabilized, quickly introduce a calibration gas to the probe of the portable gas detector.
- After introducing the calibration gas, measure and record the time required for the portable gas detector to attain a reading of 90% of the known concentration of the calibration gas.
- Repeat the steps set out in paragraphs 1, 2 and 3 two more times for a total of three repetitions.
- Determine the response time of the portable gas detector by taking the average of the three values recorded under paragraph 4.
(5) A cylinder calibration gas shall not be used for the purposes of this section unless,
- the concentration of the cylinder calibration gas has been certified by the manufacturer of the gas to be accurate within 2%, and
- the date is earlier than the expiry date set out on the label of the cylinder calibration gas.
VOCs Leak Measurement - Methodology
3. (1) As required by clause 3 (a) of this industry standard, a portable gas detector shall be used in the following manner:
- At the beginning of each day on which a portable gas detector is used, the following steps shall be taken:
- Assemble a portable gas detector that meets the criteria set out in subsection 2 (1) of this Appendix.
- Warm up the portable gas detector according to the manufacturer’s instructions.
- Determine and record,
- [Revoked]
- the calibration precision of the portable gas detector, in accordance with subsection 2 (3) of this Appendix, and
- the portable gas detector response time, in accordance with subsection 2 (4) of this Appendix.
- [Revoked]
- [Revoked]
- If a cylinder calibration gas was used for any of the steps in subparagraphs iii to v, record the manufacturer, expiry date and concentration of the cylinder calibration gas.
- To assess a component for leaks, the following steps shall be taken:
- i.1 Zero the instrument to adjust for the background concentration of VOCs.
- i. Place the probe of the portable gas detector at the component interface.
- ii. Move the probe along the component interface periphery, placing the probe as close as possible to the component interface periphery, while observing the portable gas detector readout.
- iii. If an increased instrument reading is observed, slowly sample the component interface until the maximum reading is obtained.
- iv. Leave the probe at this maximum reading location for approximately two times the portable gas detector response time.
- v. Record the maximum concentration of VOCs detected by the portable gas detector.
(1.1) At the end of each day on which a portable gas detector is used, the following steps shall be taken:
-
Determine and record,
- the calibration precision of the portable gas detector, in accordance with subsection 2 (3) of this Appendix, and
- the portable gas detector response time, in accordance with subsection 2 (4) of this Appendix.
- If a cylinder calibration gas was used for any of the steps in paragraph 1, record the manufacturer, expiry date and concentration of the cylinder calibration gas.
(2) If the component is a valve, for the purpose of subparagraph 2 i of subsection (1) place the probe at the component interface where the stem exits the packing gland and sample the stem circumference. Also, place the probe at the component interface of the packing gland take-up flange seat and sample the periphery. In addition, sample valve housings of multipart assembly at the surface of all component interfaces where a leak could occur.
(3) If the component is a connector or pressure relief device that is not designed to discharge to air, for the purpose of subparagraph 2 i of subsection (1), place the probe at the outer edge of the flange-gasket component interface and sample the circumference of the flange. Sample other types of non-permanent joints (such as threaded connections) in a similar manner.
(4) If the component is a pump or compressor, for the purpose of subparagraph 2 i of subsection (1), move the probe around the circumference of the outer surface of the pump or compressor shaft and seal component interface. If sampling a rotating shaft, position the probe within one centimetre of the shaft-seal component interface. If the housing configuration prevents a complete traverse of the shaft periphery, sample all accessible portions. Sample all other joints on the pump or compressor housing where leakage could occur.
(5) If the component is a pressure relief device that is equipped with an enclosed extension or horn and that is designed to discharge to air, for the purpose of subparagraph 2 i of subsection (1), place the probe inlet at approximately the centre of the exhaust area to the air.
(6) If the component is an open-ended valve, for the purpose of subparagraph 2 i of subsection (1), place the probe inlet at approximately the centre of the opening to the air.
(7) If the component is a sample point, instrumentation system or agitator, for the purposes of subparagraph 2 i of subsection (1), move the probe around the circumference of the outer surface of the component.
Appendix 6-E: Optical Gas Imaging - Methodology and Instrumentation
Optical Gas Imaging– OGI Instrument Requirements
1. (1) As required by clause 3 (b) of this industry standard, an OGI instrument shall meet the following criteria:
- The OGI instrument must be designed to make visible VOC air emissions that would normally be invisible to the naked eye.
- The OGI instrument must be portable.
- [Revoked]
- The OGI instrument must be capable of recording and storing images.
- The OGI instrument must record the date, time and an identifier code for each image taken by the instrument.
- [Revoked]
(2) The following information must be present at the petroleum refining facility where the OGI instrument mentioned in subsection (1) is used:
- An operating manual that sets out how to operate the OGI instrument.
- [Revoked]
- A written record of the detection limits of the OGI instrument for methane, propane, hexane and benzene.
- A written record of the maximum image storage capacity of the OGI equipment.
Optical Gas Imaging – Methodology
2. (1) As required by clause 3 (b) of this industry standard, an OGI instrument shall be used in a manner that meets the requirements set out in this section.
(2) An OGI instrument used in the performance of a component leak survey shall be calibrated at the frequency set out in the operating manual.
(3) An OGI instrument used in the performance of a component leak survey shall operate properly.
(4) Before using an OGI instrument on a day, the maximum distance at which the OGI instrument will detect VOCs shall be determined and recorded.
(5) On the day mentioned in subsection (4), the distance between an OGI instrument and the component which is being assessed by the OGI instrument shall be no greater than the distance determined in accordance with that subsection.
(6) If an OGI instrument is capable of determining the concentration of VOCs, the concentration shall be determined accurately.
Appendix 6-F: Fixed Leak Detection System - Methodology and Instrumentation
Fixed leak detection system – Instrument Requirements
1. As required by clause 3 (c) of this industry standard, a fixed leak detection system shall meet the following criteria:
- The fixed leak detection system shall be located close enough to a component to measure the concentration of VOCs discharged from the component.
- The fixed leak detection system shall be located no farther from a component mentioned in paragraph 1 than the distance set out in the operating and maintenance manual provided by a manufacturer or supplier of fixed leak detection systems.
- The fixed leak detection system shall be capable of sampling the air at least one time every 60 minutes.
- The results of the sampling and analysis shall be stored in an electronic data acquisition system.
Tracking | Date | Publishing Minister |
---|---|---|
Version 3.0 Petroleum Refining - Industry Standard |
Created June 10, 2020 | Yurek |
Version 2.0 Petroleum Refining - Industry Standard |
Created February 27, 2018 | Ballard |
Version 1.0 Petroleum Refining - Industry Standard |
Created July 27, 2016 | Murray |