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O. Reg. 530/18: AIR POLLUTION - DISCHARGE OF SULPHUR DIOXIDE FROM PETROLEUM FACILITIES

under Environmental Protection Act, R.S.O. 1990, c. E.19

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Environmental Protection Act

ONTARIO REGULATION 530/18

AIR POLLUTION - DISCHARGE OF SULPHUR DIOXIDE FROM PETROLEUM FACILITIES

Consolidation Period:  From January 1, 2019 to the e-Laws currency date.

No amendments.

This is the English version of a bilingual regulation.

Interpretation

1. (1) In this Regulation,

“acid gas combustion equipment” means equipment, such as a flare, catalytic oxidizer, thermal oxidizer or process combustion equipment, that is designed to combust acid gas which, other than when a sulphur recovery unit fails to operate in a normal manner, would be processed by a sulphur recovery unit; (“équipement de combustion de gaz acide”)

“district manager” means the district manager of the Ministry for the district in which the facility is geographically located; (“chef de district”)

“facility” means all plants, structures, equipment, apparatuses, mechanisms or things, including surfaces and storage piles, that function as a single integrated operation and that are,

(a) owned or operated by the same person, and

(b) located on the same site; (“installation”)

“licensed engineering practitioner” means a person who holds a licence, limited licence or temporary licence under the Professional Engineers Act; (“praticien de l’ingénierie titulaire d’un permis”)

“NAICS” means the North American Industry Classification System maintained for Canada by Statistics Canada, as amended or revised from time to time; (“SCIAN”)

“petroleum facility” means a facility referred to in section 3; (“installation pétrolière”)

“site”, with respect to a facility, means the property on which the facility is located. (“site”)

(2) In this Regulation, a reference to a measure with respect to minimizing, preventing or reducing flaring or other acid gas combustion or otherwise reducing discharges of sulphur dioxide includes a reference to,

(a) the implementation of operational procedures;

(b) the use of pollution control technology; and

(c) changes to equipment, processes or materials.

(3) In this Regulation, a reference to a sulphur recovery unit failing to operate in a normal manner includes,

(a) when a unit’s operation is increased from an inoperative state to normal operating conditions;

(b) when a unit’s operation is decreased from an operating state to an inoperative state;

(c) when a unit is undergoing maintenance;

(d) when a unit is in a turndown state, in a ramp up state, in hot standby mode or in an unstable operational state; or

(e) when there is a lack of availability of acid gas to feed a unit from the amine units or sour water stripper units.

(4) In this Regulation, a reference to the Director means,

(a) the Director appointed under section 5 of the Act in respect of the section of this Regulation in which the reference appears; or

(b) if no Director described in clause (a) has been appointed, any Director appointed under section 5 of the Act in respect of section 18 of the Act.

Preparation and submission of documents

2. (1) With respect to any plans, records, reports or other documents that a person creates under this Regulation,

(a) if the Director has approved a form in which to prepare the plan, record, report or other document, the person shall prepare it in that form; and

(b) if the Director has specified an electronic format in which to prepare the plan, record, report or other document, the person shall prepare it in that format.

(2) With respect to any plans, reports or other documents that a person submits to the Director, a district manager or a provincial officer under this Regulation,

(a) if the Director has approved a form in which to submit the plan, report or other document, the person shall submit it in that form; and

(b) if the Director has specified an electronic format in which to submit the plan, report or other document, the person shall submit it in that format.

Application

3. (1) This Regulation applies to a facility if,

(a) the facility is part of a class identified by NAICS code 324110; and

(b) on or before January 1, 2019,

(i) the construction of the facility was completed or began, or

(ii) an application was made for an environmental compliance approval in respect of the facility.

(2) If a petroleum facility is located on a property that is, with one or more adjacent properties, part of a deemed single property under section 4 of Ontario Regulation 419/05 (Air Pollution — Local Air Quality) made under the Act, the facilities located within the deemed single property are deemed to be a single petroleum facility for the purposes of this Regulation.

Exemptions

4. (1) On or before June 30, 2023, subsections 10 (1.1) to (1.4) of Ontario Regulation 419/05 do not apply to a person who,

(a) is required to prepare or update a report in accordance with section 26 of that Regulation in respect of a petroleum facility; and

(b) uses an approved dispersion model for that purpose.

(2) On or before June 30, 2023, section 30 of Ontario Regulation 419/05 does not apply to a person who discharges or causes or permits the discharge of sulphur dioxide from a petroleum facility if the discharge is from acid gas combustion equipment as a result of a sulphur recovery unit failing to operate in a normal manner.

Sulphur dioxide, discharge limit and reporting

5. (1) Subject to subsection (2), on or after July 1, 2019, a person shall not discharge or cause or permit the discharge of a total of more than 225 kilograms of sulphur dioxide in a 24-hour period from one or more pieces of acid gas combustion equipment at a petroleum facility.

(2) For the purposes of determining the total amount of sulphur dioxide discharged in a 24-hour period under subsection (1), any discharge that occurs when the sulphur recovery unit is operating in a normal manner must be excluded.

(3) If a discharge results in a contravention of subsection (1), the person who discharges or causes or permits the discharge of sulphur dioxide from the petroleum facility shall notify a provincial officer in writing as soon as practicable after the contravention.

(4) If a discharge results in two or more contraventions of subsection (1), after providing notice under subsection (3), the person who discharges or causes or permits the discharge of sulphur dioxide from the petroleum facility shall notify a provincial officer in writing as soon as practicable,

(a) after each subsequent contravention; or

(b) after the total amount of sulphur dioxide discharged in a 24-hour period is 225 kilograms or less.

(5) Subject to subsection (6), within 60 days after notifying a provincial officer in accordance with subsection (3) or clause 4 (a), the person who gave the notice shall submit a report to the provincial officer titled “Root Cause Analysis and Corrective Action Report” that sets out the date and time the 24-hour contravention period began and ended and the information required under subsection (7) for each piece of acid gas combustion equipment that discharged sulphur dioxide during that period.

(6) If a person has notified a provincial officer in accordance with clause 4 (b), the report required under subsection (5) shall set out the date and time each 24-hour contravention period began and ended and the information required under subsection (7) for each piece of acid gas combustion equipment that discharged sulphur dioxide during those periods.

(7) The information referred to in subsections (5) and (6) is the following:

1. The date and time the discharge from the acid gas combustion equipment began and ended.

2. Subject to subsection (8), an estimate of,

i. the flow rate of the acid gas entering the acid gas combustion equipment during the discharge; and

ii. the concentration of hydrogen sulphide in the acid gas.

3. Subject to subsection (8), an estimate of the quantity of sulphur dioxide discharged from the acid gas combustion equipment.

4. The calculations used to arrive at the estimates referred to in paragraphs 2 and 3.

5. A description of the circumstances surrounding the discharge from the acid gas combustion equipment.

6. An identification and detailed analysis of the primary cause of the discharge from the acid gas combustion equipment, including an explanation of whether it was caused by any of the following:

i. An error resulting from the improper operation of a sulphur recovery unit, a tail gas unit or any process unit upstream of a sulphur recovery unit.

ii. An error resulting from inadequate written procedures.

iii. A failure to follow written procedures.

iv. A failure of equipment that is due to a failure to operate or maintain equipment in a manner consistent with good engineering practices.

7. The steps, if any, taken to limit the duration of the discharge.

8. If the discharge was necessary to prevent an emergency, a detailed description of the emergency.

9. An identification of the measures that are available to prevent or reduce the risk of a similar discharge happening again, including,

i. the probable effectiveness of each measure,

ii. if any of the measures have already been taken, the dates those measures were implemented,

iii. if there are plans to implement any of the measures in the future, the date those measures are expected to be implemented, and

iv. if there are measures to which subparagraphs ii and iii do not apply, the reasons for not having implemented and not having plans to implement those measures.

(8) On and after the first day a continuous emissions monitoring system is installed and operated at the petroleum facility in accordance with subsection 7 (1), the estimates required under paragraphs 2 and 3 of subsection (7) of this section must be determined in accordance with the “Acid Gas Combustion Equipment Continuous Emissions Monitoring Plan” for the facility required under section 7, if the plan addresses the determination.

(9) For the purposes of paragraph 9 of subsection (7), the following measures must be considered:

1. Constructing or installing air pollution control equipment.

2. Installing and maintaining mechanisms or equipment to monitor the operations of the petroleum facility, including an alarm system or other notification system to alert personnel that combustion of acid gas is imminent.

3. Altering or redesigning industrial processes used at the petroleum facility to prevent or reduce the risk of acid gas combustion, or installing equipment for that purpose.

4. Maintaining structures, equipment or mechanisms in good repair.

Sulphur dioxide emissions calculation

6. (1) On or before March 31, 2019, a person who discharges or causes or permits the discharge of sulphur dioxide from a petroleum facility shall submit a plan to the Director titled “Sulphur Dioxide Emissions Calculation Plan” that sets out the following information:

1. Subject to subsection (2), the method the facility intends to use to calculate the amount of sulphur dioxide discharged from each piece of acid gas combustion equipment at the facility.

2. Each assumption that will be made when calculating an amount of sulphur dioxide under paragraph 1.

3. The frequency at which the facility intends to calculate the amount referred to in paragraph 1, which must be at least hourly and is only required when sulphur dioxide is being discharged from the acid gas combustion equipment when the sulphur recovery unit fails to operate in a normal manner.

(2) The method referred to in paragraph 1 of subsection (1) must assume a combustion efficiency of a flare of 98 per cent.

(3) From July 1, 2019 until the first day a continuous emissions monitoring system is installed and operated at the petroleum facility in accordance with subsection 7 (1), the person referred to in subsection (1) of this section shall calculate the following information in accordance with a Sulphur Dioxide Emissions Calculation Plan submitted under that subsection that, in the opinion of the Director, would accurately predict the amount of sulphur dioxide discharged from each piece of acid gas combustion equipment at the facility:

1. The amount of sulphur dioxide discharged from each piece of acid gas combustion equipment at the facility.

2. After making each calculation referred to in paragraph 1, the sum of the calculations required, in accordance with paragraph 3 of subsection (1), to be made in the preceding 24-hour period with respect to all acid gas combustion equipment at the facility.

(4) The person referred to in subsection (1) shall ensure that the amount of sulphur dioxide calculated in accordance with paragraph 2 of subsection (3) is made available for examination by any person, without charge,

(a) by posting it on a website of the facility, within 60 days of the amount being calculated, for a period of five years following the day the amount was posted; and

(b) by making it available during regular business hours at the facility to which the amount relates.

(5) The amounts referred to in subsection (4) may be presented in ranges, by increments of 225 kilograms.

(6) The person referred to in subsection (1) shall ensure that, with respect to the calculations referred to in subsection (3), a record of each calculation, including the date of the calculation and the amount calculated, is kept at the facility to which the record relates for a period of five years following the day on which it was created.

Continuous emissions monitoring

7. (1) Subject to subsection (2), a person who discharges or causes or permits the discharge of sulphur dioxide from a petroleum facility shall ensure that for each piece of acid gas combustion equipment at the facility, a continuous emissions monitoring system that meets the requirements set out in subsection (3) is installed and operated in accordance with a plan referred to in subsection (4) that, in the opinion of the Director, would accurately measure or predict the amount of sulphur dioxide discharged from each piece of acid gas combustion equipment.

(2) The continuous emissions monitoring system referred to in subsection (1) must be,

(a) installed no later than January 1, 2022; and

(b) operated no later than July 1, 2022.

(3) The following requirements must be met with respect to the continuous emissions monitoring system referred to in subsection (1):

1. If the amount of sulphur dioxide discharged from the acid gas combustion equipment can be measured, the continuous emissions monitoring system installed must measure the amount discharged.

2. If the amount of sulphur dioxide discharged from the acid gas combustion equipment cannot be measured, the continuous emissions monitoring system installed must measure parameters that predict the amount of sulphur dioxide discharged.

(4) On or before January 1, 2020, a person who discharges or causes or permits the discharge of sulphur dioxide from the petroleum facility referred to in subsection (1) shall submit a plan to the Director titled “Acid Gas Combustion Equipment Continuous Emissions Monitoring Plan” that sets out the following information for each piece of acid gas combustion equipment at the facility:

1. The actions required to be taken, and the frequency with which they are required to be taken, to ensure proper functioning of the acid gas combustion equipment’s continuous emissions monitoring system, including,

i. inspecting the monitoring system and performing preventative maintenance,

ii. performing equipment calibration on the monitoring system,

iii. performing data validation,

iv. ensuring visual and audible alarms function to notify staff at the facility if a set level has been exceeded,

v. auditing the accuracy of measurements, and

vi. training staff at the facility on the use and maintenance of the monitoring system.

2. If the acid gas combustion equipment’s continuous emissions monitoring system will measure the amount of sulphur dioxide discharged from the equipment, the following information:

i. The method to be used to continuously measure and record the discharge of sulphur dioxide, including how often the measurements will be taken and recorded.

ii. The locations at which the discharge of sulphur dioxide will be measured.

iii. The parameters that the monitoring system will measure, including the flow rate of and the concentration of sulphur dioxide in the gas being discharged from the acid gas combustion equipment.

3. If the acid gas combustion equipment’s continuous emissions monitoring system will measure parameters that predict the amount of sulphur dioxide, the following information:

i. A description of the stream of acid gas being sent to the acid gas combustion equipment.

ii. The method to be used to continuously measure and record the composition and flow rate of the stream of acid gas being sent to the acid gas combustion equipment, including how often the measurements will be taken and recorded.

iii. The locations at which the stream of acid gas being sent to the equipment will be measured.

iv. The parameters that the monitoring system will measure, including the following:

A. The concentration of total reduced sulphur, hydrogen sulphide and oxygen in the stream of acid gas being sent to the acid gas combustion equipment.

B. The flow rate of the stream of acid gas being sent to the acid gas combustion equipment.

C. The temperature of the combustion zone.

v. The method of calculating the following information from the parameters measured by the monitoring system, including any assumptions used in the calculations:

A. The amount of sulphur dioxide discharged from the acid gas combustion equipment.

B. The rate of emission of sulphur dioxide from the acid gas combustion equipment on at least an hourly basis when sulphur dioxide is being discharged.

(5) The method referred to in subparagraph 3 v of subsection (4) must assume a combustion efficiency of a flare of 98 per cent.

(6) If, after January 1, 2020, an existing piece of acid gas combustion equipment is modified or a new piece of acid gas combustion equipment is constructed at the petroleum facility referred to in subsection (1), the person who discharges or causes or permits the discharge of sulphur dioxide from the facility shall update and resubmit the plan under subsection (4) before the modified or new equipment is operated.

(7) The plan required under subsection (4) must be dated, signed and sealed by a licensed engineering practitioner and must set out the practitioner’s name and licence number.

(8) The person referred to in subsection (1) shall, following each measurement required by this section, calculate the total amount of sulphur dioxide discharged in the preceding 24-hour period from all acid gas combustion equipment at the facility when the sulphur recovery unit failed to operate in a normal manner.

(9) The person referred to in subsection (1) shall ensure that the amount of sulphur dioxide calculated in accordance with subsection (8) is made available for examination by any person without charge,

(a) by posting it on a website of the facility, within 60 days of the amount being measured or calculated, as the case may be, for a period of five years following the day the amount was posted; and

(b) by making it available during regular business hours at the facility to which the amount relates.

(10) The amounts referred to in subsection (9) may be presented in ranges, by increments of 225 kilograms.

(11) The person referred to in subsection (1) shall ensure that a record of the following information is kept at the facility to which the record relates for a period of five years following the day on which is was created:

1. With respect to the measurements referred to in subparagraph 2 i of subsection (4) and the calculations and measured parameters referred to in subparagraph 3 v of subsection (4), a record of each measurement and calculation, including the date of the measurement or calculation and the amount measured or calculated.

2. Each action referred to under paragraph 1 of subsection (4), including the time and date the action was taken.

Sulphur recovery unit, removal efficiency report

8. (1) On or before January 1, 2020, a person who discharges or causes or permits the discharge of sulphur dioxide from a petroleum facility shall submit a report to the district manager titled “ SRU - Removal Efficiency” that sets out the following information for the previous calendar year with respect to each sulphur recovery unit at the facility:

1. The total mass of sulphur that entered the sulphur recovery unit, in kilograms per day.

2. The total mass of sulphur that exited the sulphur recovery unit through the stack, in kilograms per day.

3. The total mass of sulphur that exited the sulphur recovery unit and was recovered as elemental sulphur, in kilograms per day.

4. The measurements and mass balance calculations used to determine the values in paragraphs 1, 2 and 3.

5. The sulphur recovery efficiency of the sulphur recovery unit, determined in accordance with the formula,

A = (B x 100) / (B + C)

in which,

“A” is the sulphur recovery efficiency, expressed as a percentage,

“B” is the mass, in kilograms per day, of sulphur referred to in paragraph 3, and

“C” is the mass, in kilograms per day, of sulphur referred to in paragraph 2.

6. The date that each measurement mentioned in paragraphs 1, 2 and 3 was taken.

(2) The measurements mentioned in paragraphs 1, 2 and 3 of subsection (1) must be taken on a day, or averaged over several days, on which the sulphur recovery unit is operating in a normal manner that would provide an accurate reflection of the unit’s sulphur recovery efficiency.

(3) The report required under subsection (1) must be dated, signed and sealed by a licensed engineering practitioner and must set out the practitioner’s name and licence number.

Flares and other combustion equipment, minimization plan

9. (1) On or before July 1, 2020, a person who discharges or causes or permits the discharge of sulphur dioxide from a petroleum facility shall submit a plan to the district manager titled “Acid Gas Combustion Minimization Plan” that sets out the following information:

1. For each piece of acid gas combustion equipment at the facility, a process flow diagram of all upstream equipment and process units that may vent to the piece of equipment.

2. For each flare at the facility that may flare acid gas, a diagram of the flare, details of the configuration of the flare nozzle and any associated air or steam injection equipment and conversion efficiency of sulphur compounds to sulphur dioxide.

3. An identification of the measures that have been taken at the facility to minimize the frequency, duration and magnitude of flaring or otherwise combusting acid gas, and the date each measure was implemented.

4. An identification of the measures that are intended to be implemented in the future to minimize the frequency, duration and magnitude of flaring or otherwise combusting acid gas at the facility, and the date those measures are expected to be implemented.

5. With respect to each measure identified under paragraphs 3 and 4, an indication of the operating condition during which the measure would minimize flaring or otherwise combusting acid gas.

6. The methodology to be followed when performing the analysis required by paragraph 6 of subsection 5 (7).

7. The methodology to be followed for the purpose of identifying the measures that are available to prevent or reduce the risk of recurrence of acid gas combustion under paragraph 9 of subsection 5 (7).

8. The following information with respect to each time sulphur dioxide was discharged from acid gas combustion equipment at the facility as a result of a sulphur recovery unit failing to operate in a normal manner in the previous calendar year:

i. The date, time and duration of the acid gas combustion and the amount of sulphur dioxide discharged during the event.

ii. The cause of the acid gas combustion, including an indication of whether the cause was recurrent failure of air pollution control equipment, process equipment or failure of a process to operate in a normal manner.

iii. A summary of all measures taken to prevent or reduce the risk of a similar acid gas combustion occurring and the date each measure was taken, including, if applicable, any measures described in a Root Cause Analysis and Corrective Action Report that were taken to prevent or reduce the risk of a similar occurrence from happening again.

(2) If, after July 1, 2020, an existing piece of acid gas combustion equipment is modified or a new piece of acid gas combustion equipment is constructed at the petroleum facility referred to in subsection (1), the person who discharges or causes or permits the discharge of sulphur dioxide from the facility shall update and resubmit the plan under subsection (1) before the modified or new equipment is operated.

(3) On or before July 1, 2021 and on or before July 1 in each subsequent year, a person who discharges or causes or permits the discharge of sulphur dioxide from the petroleum facility referred to in subsection (1) shall update the plan submitted under subsection (1) or updated under subsection (2) with information from the previous calendar year.

(4) A plan required under subsection (1) or updated under subsection (2) or (3) must be dated, signed and sealed by a licensed engineering practitioner and must set out the practitioner’s name and licence number.

(5) The person who discharges or causes or permits the discharge of sulphur dioxide from the petroleum facility referred to in subsection (1) shall ensure that a summary of the plan submitted under subsection (1) or updated under subsection (2) or (3) is, for a period of five years following the day on which the plan was submitted or updated, posted on a website of the petroleum facility,

(a) on or before December 31, 2020, with respect to the plan submitted on or before July 1, 2020; and

(b) on or before December 31 in each subsequent year with respect to the updated plans referred to in subsection (3).

Sulphur dioxide, reduction plan

10. On or before July 1, 2020, a person who discharges or causes or permits the discharge of sulphur dioxide from a petroleum facility shall submit a plan to the district manager titled “Sulphur Dioxide Reduction Action Plan” that sets out the following information:

1. An identification of the measures the facility intends to implement to reduce the emissions of sulphur dioxide from the facility in order to achieve compliance with Ontario Regulation 419/05 by July 1, 2023.

2. If any of the following measures are not identified under paragraph 1, an explanation of why those measures are not intended to be implemented:

i. Installing amine storage.

ii. Installing rich amine flash drums.

iii. Ensuring sour water separation.

iv. Installing sour water storage tanks.

v. Using oxygen enrichment.

vi. Increasing operator training.

vii. Improving instrumentation and control.

viii. Ensuring there is redundancy with respect to sulphur recovery units, tail gas treatment units and incinerators.

3. An indication of the anticipated reduction of sulphur dioxide emissions each measure identified under paragraph 1 will achieve.

4. The dates by which each measure identified under paragraph 1 is expected to be implemented at the facility.

11. Omitted (provides for coming into force of provisions of this Regulation).

 

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