SOR-2012-167 Reduction of Carbon Dioxide Emissions from Coal-fired Generation of Electricity Regulations

Part 1 sets out a performance standard for the intensity of CO 2 emissions from regulated units and provides for exceptions based on the substitution of units and for temporary exemptions in relation to emergencies and units integrated with carbon capture and storage systems;

Part 2 sets out requirements for the reporting, sending, recording and retention of information;

Part 3 sets out quantification rules for determining the intensity of CO 2 emissions from regulated units; and

Part 4 provides dates for the coming into force of these Regulations and, in particular, delays the coming into force of the performance standard in respect of standby units until January 1, 2030.

is independent of the responsible person who is to be audited; and

has demonstrated knowledge of and experience in

in respect of a responsible person that is a corporation, an officer of the corporation who is authorized to act on its behalf;

in respect of a responsible person that is an individual, that person or a person authorized to act on that individual’s behalf; and

in respect of a responsible person that is another entity, a person authorized to act on that other entity’s behalf. (agent autorisé)

for an electricity generator that began producing electricity by means of thermal energy using a fuel other than coal, and not in conjunction with coal, but that was converted into a unit before June 23, 2010, the day on which that generator began to produce electricity for sale to the electric grid using fuel other than coal, and not in conjunction with coal; and

in any other case, the day on which a unit begins to produce electricity for sale to the electric grid. (date de mise en service)

technical drawings and documents that describe the capture element in sufficient detail to permit the tendering of a contract for its construction;

an estimation of the capital cost of the capture element with a margin of error of ± 20%;

a safety review of the capture element;

a risk assessment of the carbon capture and storage system, namely an assessment of the risks that may delay or prevent the completion of the construction of the system, including technical, economic, environmental, legal and labour-related risks;

a strategy to mitigate those risks; and

a detailed plan to carry out the construction of the carbon capture and storage system, including a schedule for the completion of its major steps. (étude d’ingénierie d’avant-projet détaillé)

is manufactured in accordance with specifications in its purchase order and takes more than 12 months after the date of the purchase order to be manufactured and delivered; or

costs $10,000,000 or more. (équipement majeur)

the maximum continuous rating of the unit, expressed in MW, as most recently reported to a provincial authority of competent jurisdiction or to the electric system operator in the province where the unit is located; or

if no report has been made, the most electricity that was produced for sale by the unit, expressed in MW, during two continuous hours in that calendar year. (capacité de production)

for a unit other than a unit referred to in paragraph (a) of the definition commissioning date,

for a unit referred to in paragraph (a) of the definition commissioning date, 18 months after the applicable date described in paragraph (a). (vie utile)

electricity referred to in subsection (1) is to be determined in accordance with section 19; and

emissions referred to in subsection (1) are to be determined in accordance with the applicable provisions of sections 20 to 24.

are captured in accordance with the laws of Canada or a province that regulate that capture;

are transported and stored in accordance with the laws of Canada or a province, or of the United States or one of its states, that regulate that transportation or storage, as the case may be; and

are not subsequently released into the atmosphere.

the substituted unit is an existing unit;

the original unit and the substituted unit have a common owner who has an ownership interest of 50% or more in each of those two units;

those two units are located in the same province; and

the production capacity of the substituted unit, during the calendar year preceding the calendar year in which the application is made, was equal to or greater than the production capacity of the original unit during that preceding calendar year.

the substituted unit is not a shut-down unit referred to in subsection 6(4);

the substituted unit is not involved in an exemption granted under subsection 14(4); and

the Minister is satisfied that the conditions of paragraphs (1)(a) to (d) are satisfied.

July 1, 2015, and

the beginning of the calendar year that follows the calendar year in which the application is made.

the calendar year that follows the day on which the responsible person for that unit and the substituted unit sends the Minister a notice indicating that they wish the substitution to no longer have an effect,

the calendar year that follows the day on which the condition of paragraph (1)(b) is no longer satisfied,

the calendar year that follows a calendar year during which the production capacity of the original unit was more than the production capacity of the substituted unit referred to in paragraph (1)(d),

the calendar year that follows the end of the useful life of the substituted unit, and

a calendar year during which electricity is produced by the substituted unit by means of thermal energy using fossil fuel other than coal, and not in conjunction with coal.

the shut-down unit and each of the specified deferred units have a common owner who has an ownership interest of 50% or more in the shut-down unit and in each of those specified deferred units;

the shut-down unit and each of those specified deferred units are located in the same province; and

the production capacity of the shut-down unit, during the calendar year preceding the day on which it ceased production, was greater than or equal to the production capacity of each of those specified deferred units during the calendar year preceding the day on which the application was made.

indicate the calendar years included in the period referred to in subsection (1);

specify the deferred unit referred to in subsection (1) in respect of each of the calendar years referred to in paragraph (a);

for each of those specified deferred units in respect of each of those calendar years, specify the calendar year that begins after the end of the useful life of the unit for which the application of subsection 3(1) is to be deferred;

indicate the registration number of the shut-down unit and of each of the specified deferred units; and

include information, with supporting documentation, to demonstrate that the conditions of paragraphs (2)(a) to (c) are satisfied.

the shut-down unit is not a substituted unit referred to in subsection 5(5);

no deferred unit is a unit that is involved in a temporary exemption granted under subsection 9(3); and

the Minister is satisfied that the conditions of paragraphs (2)(a) to (c) are satisfied;

the registration number of the proposed new specified deferred unit;

the calendar year that begins after the end of the useful life of the proposed new specified deferred unit for which the application of subsection 3(1) is to be deferred; and

information, with supporting documentation, to demonstrate that the conditions of paragraphs (2)(a) and (b) are satisfied in respect of the proposed new specified deferred unit and the condition of paragraph (2)(c) is satisfied in respect of each specified deferred unit, including the proposed new specified deferred unit, during the calendar year preceding the day on which the notification is sent.

the calendar year that follows the calendar year in which the application is made, if a shut-down unit referred to in subsection (1) has not ceased to produce electricity by January 1 of that following calendar year,

any calendar year in which a shut-down unit referred to in subsection (1) recommences to produce electricity,

the calendar year that follows the day on which the Minister receives a notice from the responsible person for the shut-down unit and the deferred units indicating that they wish the deferral to no longer have an effect,

the calendar year that follows the day on which the condition of paragraph (2)(a) is no longer satisfied, and

the calendar year that follows a specified calendar year referred to in paragraph (3)(c) in which the specified deferred unit referred to in that paragraph had a production capacity greater than the production capacity of the shut-down unit during the calendar year preceding the day on which it ceased production.

as a result of the emergency circumstances, there is a disruption, or a significant risk of disruption, to the electricity supply in the province where the unit is located; and

the operation of the unit will end, decrease the risk of, or mitigate the consequences of, the disruption.

that arises due to an extraordinary, unforeseen and irresistible event; or

under which one or more of the measures referred to in paragraph 1(a) of the Regulations Prescribing Circumstances for Granting Waivers Pursuant to Section 147 of the Act has been made or issued in the province where the unit is located.

the day that is 90 days after that day,

the day specified by the Minister, and

the earlier of

paragraphs 7(1)(a) and (b) will continue to apply after the day on which the exemption is to cease to have effect; and

steps — other than the operation of the unit during the period of the exemption — have been, and are being, taken to end, decrease the risk of, or mitigate the consequences of, the disruption.

the day that is 90 days after the day on which the application for the extension was made,

the day specified by the Minister, and

the day referred to in paragraph 7(5)(c).

in the case of a new unit, the unit is designed to permit its integration with a carbon capture and storage system that is to be constructed; and

in the case of an old unit, the unit may be retrofitted to permit its integration with a carbon capture and storage system that is to be constructed.

a declaration that includes statements indicating that

an economic feasibility study that demonstrates the economic viability of the unit when it operates with an integrated carbon capture and storage system and that

a technical feasibility study that establishes — based on information referred to in Schedule 2 related to the capture, transportation and storage elements of the carbon capture and storage system — that there are no insurmountable technical barriers to carrying out the following activities:

a description of any work that has been done to satisfy the requirements set out in section 10, along with the information referred to in Schedule 3 with respect to that work; and

an implementation plan that provides a description of the work to be done, with a schedule for the steps necessary to achieve the following objectives:

the application includes the documents referred to in subsection (2); and

the information contained in those documents can reasonably be regarded as establishing that

carry out a front end engineering design study by January 1, 2020;

purchase any major equipment that is necessary for the capture element by January 1, 2021;

enter into any contract required for the transportation and storage of CO 2 emissions from the unit by January 1, 2022;

take all necessary steps to obtain all permits or approvals required in relation to the construction of the capture element by January 1, 2022; and

ensure that the unit, when operating with an integrated carbon capture and storage system, captures CO 2 emissions from the combustion of fossil fuels in the unit in accordance with the laws of Canada or a province that regulate that capture and transports and stores those emissions in accordance with the laws of Canada or a province, or of the United States or one of its states, that regulate that transportation or storage, as the case may be, by January 1, 2024.

the steps taken during that year to construct the capture, transportation and storage elements of the carbon capture and storage system and to integrate those elements with the unit;

any requirement set out in section 10 that was satisfied during that year, along with the information and documents referred to in Schedule 3;

a description of the manner in which those steps were carried out or those requirements were satisfied;

any changes, with respect to the information most recently provided to the Minister, to the proposed engineering design for the capture element, to the preferred transportation methods or routes or to the preferred storage sites, for the carbon capture and storage system; and

a description of any steps necessary, with a schedule for those steps, to achieve the following objectives:

a description of the event or circumstance and the nature of the prejudice;

an explanation of how the prejudice is to be overcome in order to ensure that the objective will be achieved; and

in relation to that explanation, an update to any information previously provided to the Minister under paragraphs 11(1)(c) to (e), together with any necessary supporting documents.

the responsible person does not satisfy a requirement set out in section 10; or

any information indicated or contained in the application for the temporary exemption, in an implementation report referred to in section 11 or in a notice referred to in section 12 is false or misleading.

the responsible person has not provided an implementation report in accordance with section 11;

there are reasonable grounds for the Minister to believe that the carbon capture and storage system will not operate so as to capture, transport and store CO 2 emissions as described in paragraph 10(e) by the date referred to in that paragraph; or

there are reasonable grounds for the Minister to believe that the responsible person will not emit CO 2 from the combustion of fossil fuels in the unit in accordance with subsection 3(1) by January 1, 2025.

written reasons for the proposed revocation; and

an opportunity to be heard, by written representation, in respect of the proposed revocation.

an existing unit and the old unit have a common owner who has a ownership interest of 50% or more in each of those two units;

the production capacity of the existing unit, during the calendar year preceding the calendar year in which the application is made, was equal to or greater than the production capacity of the old unit during that preceding calendar year;

the existing unit and the old unit are located in the same province;

the quantity of CO 2 emissions from the combustion of fossil fuels in the existing unit is determined in accordance with a system or method referred to in subsection 20(1);

the quantity of CO 2 emissions from the combustion of fossil fuels in the existing unit that are captured, transported and stored is determined using a direct measure of the flow of, and the concentration of CO 2 in, the emissions from that combustion of fuel;

the emissions referred to in paragraph (e) are captured in accordance with the laws of Canada or a province that regulate that capture and are transported and stored in accordance with the laws of Canada or a province, or of the United States or one of its states, that regulate that transportation or storage, as the case may be;

the emissions referred to in paragraph (e) are captured, transported and stored for a period of seven consecutive calendar years;

the emissions referred to in paragraph (e) comprise at least 30% of the quantity of CO 2 emissions produced from the combustion of fossil fuels in the existing unit for each calendar year during that seven-year period; and

the existing unit does not reach the end of its useful life during that seven-year period.

the conditions of paragraphs (1)(a) to (f), (h) and (i) are satisfied; and

at least 30 consecutive months of the period referred to in paragraph (1)(g) have occurred before the day on which the application is made.

no exemption referred to in subsection (1) has been previously granted in respect of the old unit;

no exemption referred to in subsection (1) that involved the existing unit has been previously granted;

the existing unit referred to in subsection (1) is not a substituted unit referred to in subsection 5(5); and

the Minister is satisfied that the requirements set out in subsection (3) are satisfied.

a new unit;

an old unit;

a substituted unit referred to in subsection 5(5);

an existing unit referred to in subsection 14(1), if that calendar year is a calendar year included in the remaining portion of the seven consecutive calendar years referred to in subsection 14(5).

of any notice referred to in subsection 4(3), 5(6) or 6(6) or section 12 that was sent to the Minister and the information that was contained in it, as well as any supporting documents;

of any application referred to in subsection 5(3), 6(3), 7(3), 8(2), 9(2) or 14(3) and the information referred to in the subsection, as well as any supporting documents;

of every direct measure of the flow of, and the concentration of CO 2 in, emissions referred to in paragraph 14(1)(e), subsection 20(2) and the descriptions of E non-ccs in subsection 21(1) and of E ccs in section 22;

of every measurement and calculation used to determine a value of an element of a formula set out in any of sections 19 and 21 to 24;

that demonstrates that any meter referred to in section 19 complies with the requirements of the Electricity and Gas Inspection Act and the Electricity and Gas Inspection Regulations, including a certificate referred to in section 14 of that Act;

for each calendar year during which a responsible person used a continuous emission monitoring system referred to in paragraph 20(1)(a), of any document, record or information referred to in section 8 of the Reference Method;

that demonstrates that the installation, maintenance and calibration of measuring devices referred to in subsection 25(1) was in accordance with that subsection and subsection 25(3) and of every calibration referred to in subsection 25(2); and

of the results of the analysis of every sample collected in accordance with section 27.

during a subsequent calendar year, a unit located at the power plant ceases to produce electricity or a new unit is added to those located at the power plant; or

during a subsequent calendar year, the operation of any unit located at the power plant is integrated with a carbon capture and storage system.

by using a continuous emission monitoring system (CEMS) in accordance with section 21; or

by using a fuel-based method, based on the quantity of carbon in the fossil fuel fed for combustion, in accordance with section 22 and section 23 or 24.

the volume of CO 2 emitted from combustion of fuel in the unit for each hour of production of electricity during the calendar year determined in accordance with the following formula: 0.01 × %CO 2w,h × Q w,h × t h where%CO 2w,h is the average concentration of CO 2 in relation to all gases in the stack emitted from the combustion of fuel in the unit during a given hour, “h”, during which the unit produced electricity in the calendar year — or, if applicable, a calculation made in accordance with section 7.4 of the Reference Method of that average concentration of CO 2 based on a measurement of the concentration of oxygen (O 2) in those gases in the stack — expressed as a percentage on a wet basis, Q w,h is the average volumetric flow during that hour, measured on a wet basis by the stack gas volumetric flow monitor, expressed in standard m 3, and t h is the period during which the unit produced electricity, expressed in hours;

the volume of CO 2 emitted from combustion of fossil fuel in the unit during the calendar year, expressed in standard m 3 and referred to in this subsection as V ff, determined in accordance with the following formula: The formula for determining the volume of CO2 emissions emitted from the combustion of fossil fuel in the unit during the calendar year is the sum of the products resulting from the multiplication of Qi, Fc,i and HHVd,i for each fossil fuel type “i” combusted in the unit during the calendar year. where Q i is the quantity of fossil fuel type “i” combusted in the unit during the calendar year, determined for a solid fuel, in the same manner as the one used in the determination of M f in the formula set out in paragraph 23(1)(a) and expressed in tonnes, for a liquid fuel, in the same manner as the one used in the determination of V f in the formula set out in paragraph 23(1)(b) and expressed in kL, and for a gaseous fuel, in the same manner as the one used in the determination of V f in the formula set out in paragraph 23(1)(c) and expressed in standard m 3, i is the i th fossil fuel type combusted in the unit during the calendar year, with “i” going from the number 1 to n, where n is the number of fossil fuels so combusted, F c,i is the fuel-specific carbon-based F-factor for each fossil fuel type “i” — being, as the case may be, the default value as set out in column 3 of the table to subsection (3) for that fuel type set out in column 2 or determined for that fuel type in accordance with Appendix A of the Reference Method — expressed in standard m 3 of CO 2/GJ, HHV d,i— expressed in GJ/tonne, for a solid fuel, in GJ/kL, for a liquid fuel, and in GJ/standard m 3, for a gaseous fuel — is, for each fossil fuel type “i”, the default higher heating value set out in column 2 of Schedule 5 for that fuel type set out in column 1, and in the absence of a default higher heating value for that fuel type referred to in paragraph (a), a default higher heating value for that fuel type established by a body that is internationally recognized as being competent to establish default higher heating values for fuels;

the volume of CO 2 emitted from the combustion of biomass in the unit during the calendar year, expressed in standard m 3 and referred to in this subsection as V bio, determined in accordance with the following formula: V T – V ff where V T is the sum of the volumes of CO 2 emitted from combustion of fuel in the unit during each hour of production of electricity during the calendar year, as determined under paragraph (a), and V ff is V ff determined in accordance with the formula set out in paragraph (b); and

the quantity of the CO 2 emissions from the combustion of biomass in the unit during the calendar year, namely E bio determined in accordance with the formula set out in subsection (1), based on the following two determinations:

for a solid fuel M f × CC A × 3.664 where M f is the mass of the fuel combusted during the calendar year as determined, as the case may be, on a wet or dry basis, expressed in tonnes and measured by a measuring device, and CC A is the weighted average, expressed in kg of carbon per kg of the fuel, of the carbon content of the fuel determined in accordance with subsection (2) on the same wet or dry basis as the one used in the determination of M f;

for a liquid fuel V f × CC A × 3.664 where V f is the volume of the fuel combusted during the calendar year, expressed in kL, determined by using flow meters, and CC A is the weighted average, expressed in tonnes of carbon per kL of the fuel, of the carbon content of the fuel determined in accordance with subsection (2) at the same temperature as the one used in the determination of V f; and

for a gaseous fuel The formula for determining the quantity of CO2 emissions attributable to a gaseous fuel is the product resulting from the multiplication of Vf, CCa, the constants of 3.664, the constant 0.001, and the quotient of MMa over MVcf. where V f is the volume of the fuel combusted during the calendar year, expressed in standard m 3, determined by using flow meters, CC A is the weighted average, expressed in kg of carbon per kg of the fuel, of the carbon content of the fuel determined in accordance with subsection (2), MM A is the average molecular mass of the fuel, expressed in kg per kg-mole of the fuel, determined based on fuel samples collected in accordance with section 27, and MV cf is the molar volume conversion factor, namely 23.645 standard m 3 per kg-mole of the fuel at standard conditions of 15°C and 101.325 kPa.

the higher heating value of the fuel that is measured in accordance with subsection (6) as provided by the supplier of the fuel to the responsible person but, if not so provided, as so measured by the responsible person; and

in the absence of a measured higher heating value of the fuel referred to in paragraph (a), the default higher heating value, set out in column 2 of Schedule 5, for the fuel’s type, as set out in column 1 but, in the absence of that default higher heating value, a default higher heating value for that fuel type established by a body that is internationally recognized as being competent to establish default higher heating values for fuels.

a fuel combusted in a unit in respect of which an exemption from the application of subsection 3(1) has been granted under subsection 7(4);

a fuel referred to in section 23 that is combusted during the calendar year at less than any of the average daily rates referred to in subsection (3);

a fuel listed in Table 4 to Schedule 5; and

a fuel combusted in a standby unit.

for a solid fuel, 3 t/day;

for a liquid fuel, 1900 L/day; and

for a gaseous fuel, 500 standard m 3/day.

for a solid fuel that is

for a liquid fuel that is

for a gaseous fuel,

at least once in every calendar year but at least five months after a previous calibration, and

the minimum frequency recommended by the manufacturer.

assess, based on the review referred to in section 6.5.2 of the Reference Method, whether, in the auditor’s opinion, the responsible person’s use of the CEMS complied with the Quality Assurance/Quality Control manual referred to in section 6 of the Reference Method;

ensure that the Quality Assurance/Quality Control manual has been updated in accordance with sections 6.1 and 6.5.2 of the Reference Method; and

assess whether, in the auditor’s opinion, the responsible person complied with the Reference Method and the CEMS met the specifications set out in the Reference Method, in particular, in its sections 3 and 4.

for coal other than synthetic gas derived from coal or derived from petroleum coke, one composite sample, during each week that the unit produces electricity, that is prepared in accordance with ASTM D2013 / D2013M - 11, entitled Standard Practice for Preparing Coal Samples for Analysis, and that consists of sub-samples taken at least twice from coal that was fed for combustion during that week and at least 48 hours apart, in accordance with

for a type of solid fuel other than coal, one composite sample per month that consists of sub-samples of fuel of that type, each having the same mass, that were taken from fuel that was fed for combustion during each week that begins in that month and during which the unit produces electricity and that were taken at least 48 hours after any previous sub-sample and after all fuel treatment operations had been carried out but before any mixing of the fuel from which the sub-sample is taken with other fuels;

for a type of liquid fuel and of a gaseous fuel other than natural gas, one sample per quarter, with each sample of fuel of that type being taken at least one month after any previous sample has been taken; and

for natural gas, two samples per calendar year, with each sample being taken at least four months after any previous sample has been taken.

an indication of whether they are the owner or operator of the unit and their name and civic address;

the name, title, civic and postal addresses, telephone number and, if any, email address and fax number, of their authorized official; and

the name, title, civic and postal addresses, telephone number and, if any, email address and fax number, of a contact person, if different from the authorized official.

for each responsible person for the unit, other than the responsible person mentioned in paragraph 1(a), if any

its name and civic address, if any;

if applicable, its National Pollutant Release Inventory identification number assigned by the Minister for the purpose of section 48 of the Act;

for an existing or old unit, the calendar year in which it reaches, or has reached, the end of its useful life;

its commissioning date; and

its production capacity.

a description of how the emissions are to be captured, including a preliminary engineering design and a description of the preferred technology and processes to be used;

a description of the principal modifications to the unit that are needed for its integration with the capture element to enable the responsible person to comply with subsection 3(1) of these Regulations;

an identification of any major equipment to be installed and of any other significant equipment to be modified or replaced;

process flow diagrams and mass and energy balances, including external energy inputs;

a summary of auxiliary energy loads;

an estimate of the unit’s production capacity when it is operating with an integrated capture element;

an estimate of the unit’s gross quantity of electricity produced for a calendar year — set out in the description of G gross in subsection 19(1) of these Regulations — when it is operating with an integrated capture element;

an estimate of the rate of capture of CO 2 emissions and of the volume of CO 2 emissions, expressed in standard m 3, to be captured for a calendar year and for the operating life of the unit;

a preliminary resource analysis for the unit when it is operating with an integrated capture element, including water consumption, heat and power consumption, raw material consumption and fuel consumption;

documents establishing that adequate space has been set aside at the power plant in which the unit is located and that adequate access is to be provided for the purpose of installing the required equipment, including site plans that show

an identification of the potential risks and obstacles, based on the preferred capture technology, to the construction and operation of the capture element integrated with the unit;

a list of each environmental, safety and other approval or permit that is required for the construction or operation of the unit integrated with the capture element; and

a list of potential suppliers of equipment, materials or services that are needed for the construction and operation of the unit integrated with the capture element.

an identification of, and justification for, one or more preferred transport methods and routes to an appropriate geological storage site referred to in paragraph 3(b), supported by a routing map and a geographic information system (GIS) file for each method and route;

the expected location and size of pumping stations, of receipt and delivery points and of any interconnects on the pipeline for each preferred route;

an estimation of the diameter of the pipeline for each preferred route that is required to transport the sufficient volume of CO 2 referred to in subparagraph 9(2)(c)(i) of these Regulations;

if applicable, a detailed description of how any tankers that are to be used to transport the captured CO 2 emissions are to be obtained and, if required, commissioned and a plan detailing how any required port infrastructure for shipping the captured CO 2 emissions on those tankers is to be developed;

an identification of the potential risks and obstacles, for each preferred route, to the construction and operation of the pipeline or shipping network along that route, including any surface or subsurface land use that may conflict with that construction or operation, along with an explanation of how those risks and obstacles are to be overcome ;

a list of each environmental, safety and other approval or permit that is required for the construction or operation of the transportation element; and

a list of potential suppliers of equipment, materials or services that are needed for the construction and operation of the transportation element.

an estimation of the volume of CO 2 emissions, expressed in standard m 3, to be captured and stored during each calendar year and over the anticipated operating life of the unit;

an identification of one or more suitable geological sites for storage that are expected to be used to store the captured CO 2 emissions, supported by a delineation of the geographical extent of each storage site and at least one study showing that the required capacity to store the sufficient volume of CO 2 referred to in subparagraph 9(2)(c)(i) of these Regulations is available based on generally accepted national or international protocols for storage capacity estimation;

an identification of any requirement under federal or provincial laws for the purity of captured CO 2 emissions, along with an explanation of how that requirement is to be met;

a preliminary assessment of the integrity of the storage element in preserving an impervious barrier to leakage of stored CO 2 emissions and of any risk to breaching that integrity, at each feasible storage site referred to in paragraph (b), along with a preliminary strategy to mitigate the risk;

a preliminary plan for measuring and verifying the volume of stored CO 2 emissions and for monitoring any leak of the stored CO 2 emissions from the storage element;

an identification of any surface or subsurface land use that may conflict with the operation of the storage element at each feasible storage site referred to in paragraph (b), along with an explanation of how the conflict is to be resolved in order to ensure access to each of those sites;

a list of each environmental, safety and other approval or permit that is required for the construction or operation of the storage element; and

a list of potential suppliers of equipment, materials or services that are needed for the construction and operation of the storage element for each feasible site referred to in paragraph (b).

an overall description of the construction project for the carbon capture and storage system, including technical drawings and documents that describe

an estimate of capital cost of the construction project, including a summary of the analysis that led to that estimate and a justification for the margin of error of that estimate;

a summary of the safety review of the capture element of the carbon capture and storage system;

a summary of the risk assessment of the carbon capture and storage system;

a summary of the strategy to mitigate those risks;

a summary of the plan to carry out the construction of the carbon capture and storage system, including a schedule for the completion of its major steps;

an identification of potential persons with whom agreements can be entered into to carry out the construction of the carbon capture and storage system;

the name and business address of the persons responsible for the development of the front end engineering design study and a description of their contribution to its development;

a description of the capture technology selected in the front end engineering design study for the capture element of the carbon capture and storage system and of the capture element’s integration with the unit;

an identification of any major equipment required to be purchased for the construction of the capture element of the carbon capture and storage system;

an estimate of the performance of the unit when it is operating with an integrated carbon capture and storage system, supported by process flow diagrams and mass and energy balances, including an estimate of

a summary of the resource analysis for the unit when it is operating with an integrated capture element of the carbon capture and storage system, including water consumption, heat and power consumption, raw material consumption and fuel consumption.

an indication of whether they are the owner or operator of the unit and their name and civic address;

the name, title, civic and postal addresses, telephone number and, if any, email address and fax number, of their authorized official; and

the name, title, civic and postal addresses, telephone number and, if any, email address and fax number, of a contact person, if different from the authorized official.

for each responsible person for the unit, other than the responsible person mentioned in paragraph 1(a), if any

its name and civic address, if any;

its registration number and, if applicable, its National Pollutant Release Inventory identification number assigned by the Minister for the purpose of section 48 of the Act;

if applicable, the number of other units located at the power plant in which the unit is located and, for each of those other units, the information referred to in paragraph (a); and

if applicable, a statement that indicates that the unit shares a common stack with one or more of those other units, along with a statement that identifies each of those other units.

the emission-intensity for the unit, namely the ratio of the quantity of CO 2 emissions referred to in paragraph (c) to the quantity of electricity referred to in subparagraph (b)(i), expressed in tonnes per GWh;

in respect of the quantity of electricity produced by the unit

in respect of the quantity of CO 2 emissions from the combustion of fuels in the unit,

if applicable, documents that establish that the captured CO 2 emissions were captured, transported and stored as described in subsection 3(5) of these Regulations;

if applicable, the quantity of CO 2 emissions that were captured, determined using a direct measure of the flow of, and the concentration of CO 2 in, those emissions; and

for each type of fuel combusted,

the number of hours during which the unit produced electricity;

if a substituted unit referred to in subsection 5(1) of these Regulations has been substituted for an original unit, the production capacity of that substituted unit;

for a standby unit, the capacity factor for the standby unit;

for a unit granted an exemption under subsection 7(4) of these Regulations,

for an existing unit referred to in subsection 14(4) of these Regulations, the percentage of CO 2 emissions from the unit that are captured, transported and stored, along with supporting documents to establish the validity of that percentage.

the reason for which data required to determine the value of an element of a formula set out in section 19 or any of sections 21 to 24 of these Regulations was not obtained and an explanation as to why that reason was out of the control of the responsible person;

the element of the formula for which data was not obtained and the date of the day on which the data was not obtained and, if that data was not obtained for a period of several days, the dates of the days on which the period begins and ends; and

the value determined for that element using replacement data, along with details of that determination, including

the responsible person’s use of the CEMS complied with the Quality Assurance/Quality Control manual referred to in section 6 of the Reference Method; and

the responsible person complied with the Reference Method and the CEMS meets the specifications set out in the Reference Method, in particular, in its sections 3 and 4.

the responsible person’s use of the CEMS complied with the Quality Assurance/Quality Control Manual referred to in section 6 of the Reference Method; and

the responsible person complied with the Reference Method and the CEMS has met the specifications set out in the Reference Method, in particular, in its sections 3 and 4.