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Q-2, r. 46.1 - Regulation respecting a cap-and-trade system for greenhouse gas emission allowances

Full text

In force date

2021-07-15 Show full text at this date

APPENDIX D

(ss. 70.1 to 70.22)

This Appendix is deemed to be a regulation of the Minister made under the second paragraph of section 46.8 of the Environment Quality Act. (S.Q. 2017, c. 4, s. 285)

Offset credit protocols

For the purposes of these protocols,

(1) “standard conditions” means a temperature of 20 °C and pressure of 101.325 kPa;

(2) “SSR” means GHG sources, sinks and reservoirs on the project site.

PROTOCOL 1

COVERED MANURE STORAGE FACILITIES – CH4 DESTRUCTION

Part I

(1) Projects covered

This offset credit protocol covers any project designed to reduce GHG emissions by destroying the CH4 attributable to the manure of an agricultural operation in Québec raising one of the species of livestock listed in the tables in Part II.

The project involves the installation of a manure storage facility cover and a fixed CH4 destruction device.

The project must enable to capture and destroy CH4 that, before the project, was emitted to the atmosphere. The CH4 must be destroyed on the site of the manure storage facility where the CH4 was captured, using a flare or any other device.

For the purposes of this protocol, “manure” means livestock waste with liquid manure management within the meaning of the Agricultural Operations Regulation (chapter Q-2, r. 26).

(2) Location

The project must be carried out within the borders of the province of Québec.

(3) Reduction project SSRs

The process flow chart in Figure 3.1 and the table in Figure 3.2 show all the SSRs that must be taken into account by the promoter when calculating the GHG emission reductions attributable to the project.

All the SSRs within the dotted line must be counted for the purposes of this protocol.

Figure 3.1. Flowchart for the reduction project process

Figure 3.2. Reduction project SSRs

(4) Calculation method for the GHG emission reductions attributable to the project

The promoter must calculate the quantity of GHG emission reductions attributable to the project using equation 1:

Equation 1

Where:

ER = Reductions in GHG emissions attributable to the project during the issuance period, in metric tonnes CO2 equivalent;

GHG project = Gross reduction in GHG emissions from the project during the issuance period, calculated using equation 2, in metric tonnes CO2 equivalent;

/\GHG fossil = Differential between GHG emissions in the baseline scenario and GHG emissions for the project attributable to the fossil fuels consumed in the operation of equipment within the project SSRs, during the issuance period, calculated using equation 9, in metric tonnes CO2 equivalent.

(4.1) Calculation method for gross GHG emission reductions

The promoter must calculate the quantity of gross GHG emission reductions attributable to the project using equations 2 to 8:

Equation 2

GHG project = GHG dest flare - GHG combustion flare + GHG dest other - GHG combustion other

Where:

GHG project = Gross reduction in GHG emissions attributable to the project during the issuance period, in metric tonnes CO2 equivalent;

GHG dest flare = Lesser of the CH4 emissions destroyed at flare during the issuance period and 90% of the emissions from an uncovered manure storage facility, calculated using equation 3, in metric tonnes CO2 equivalent;

GHG combustion flare = N2O emissions attributable to combustion of captured gas at flare during the issuance period, calculated using equation 6, in metric tonnes CO2 equivalent;

GHG dest other = Lesser of the CH4 emissions destroyed by a destruction device other than a flare during the issuance period and 90% of the emissions from an uncovered manure storage facility, calculated using equation 7, in metric tonnes CO2 equivalent;

GHG combustion other = N2O emissions attributable to combustion of captured gas by a destruction device other than a flare during the issuance period, calculated using equation 8.1, in metric tonnes CO2 equivalent;

Equation 3

GHG dest flare = Min [GHG flare; GHG EF]

Where:

GHG dest flare = Lesser of the CH4 emissions destroyed at flare during the issuance period and 90% of the emissions from an uncovered manure storage facility, in metric tonnes CO2 equivalent;

Min = Lesser of the 2 elements calculated;

GHG flare = CH4 emissions destroyed at flare during the issuance period, calculated using equation 4, in metric tonnes CO2 equivalent;

GHG EF = 90% of emissions from an uncovered manure storage facility, calculated using equation 5, in metric tonnes CO2 equivalent;

Equation 4

Where:

GHG flare = CH4 emissions destroyed at flare during the issuance period, in metric tonnes CO2 equivalent;

n = Number of days on which gas is produced during the issuance period;

j = Day on which gas is produced at the manure storage facility;

Q gas cov = Quantity of gas available for burning on day j measured at the capture system before delivery to the flare, in cubic metres at standard conditions;

EFF flare = Flare burning efficiency rate, namely:

— for an open flare, a rate of 0.96 when the flare is operated in accordance with the method General control device and work practice requirements in Part 60.18 of Title 40 of the Code of Federal Regulation published by the U.S. Environmental Protection Agency (USEPA), or a rate of 0.5 in other cases;

— for an enclosed flare, a rate of 0.98 when the gas retention time in the stack is at least 0.3 seconds, or a rate of 0.9 in other cases;

C CH4 = Average CH4 content in the gas burned on day j, determined in accordance with Part III, in cubic metres of CH4 per cubic metre of gas;

0.667 = Density of CH4, in kilograms per cubic metre at standard conditions;

21 = Global Warming Potential factor of CH4;

0.001 = Conversion factor, kilograms to metric tonnes;

Equation 5

Where:

GHG EF = 90% of the emissions from a non-covered manure storage facility, in metric tonnes CO2 equivalent;

n = Number of categories of livestock;

i = Category of livestock listed in the tables in Part II;

Nbi = Population of category of livestock i during the issuance period, in head of livestock;

EFi = CH4 emission factor for category of livestock i, specified in the tables in Part II, in kilograms of CH4 per head per year;

21 = Global Warming Potential factor of CH4;

0.001 = Conversion factor, kilograms to metric tonnes;

0.9 = 90%;

Equation 6

Where:

GHG combustion flare = N2O emissions attributable to combustion of captured gas at flare during the issuance period, in metric tonnes CO2 equivalent;

n = Number of days on which gas is produced during the issuance period;

j = Day on which gas is produced at the manure storage facility vent;

Q gas cov = Quantity of gas available for burning on day j measured at the capture system before delivery to the flare, in cubic metres at standard conditions;

EFF flare = Flare burning efficiency rate, namely:

— for an open flare, a rate of 0.96 when the flare is operated in accordance with the method “General control device and work practice requirements” in Part 60.18 of Title 40 of the Code of Federal Regulations published by the U.S. Environmental Protection Agency (USEPA), or a rate of 0.5 in other cases;

— for an enclosed flare, a rate of 0.98 when the gas retention time in the stack is at least 0.3 seconds, or a rate of 0.9 in other cases;

C CH4 = Average CH4 content in the gas burned on day j, determined in accordance with Part III, in cubic metres of CH4 per cubic metre of gas;

0.049 = N2O emission factor attributable to flare burning, in grams of N2O per cubic metre of gas burned;

310 = Global Warming Potential factor of N2O;

0.000001 = Conversion factor, grams to metric tonnes;

Equation 7

GHG dest other = Min [GHG other ; GHG EF]

Where:

GHG dest other = Lesser of CH4 emissions destroyed by a destruction device other than a flare during the issuance period and 90% of emissions from an uncovered manure storage facility, in metric tonnes CO2 equivalent;

Min = Lesser of the 2 elements calculated;

GHG other = CH4 emissions destroyed by the destruction device other than a flare during the issuance period, calculated using equation 8, in metric tonnes CO2 equivalent;

GHG EF = 90% of the emissions from a non-covered manure storage facility, calculated using equation 5, in metric tonnes CO2 equivalent;

Equation 8

Where:

GHG other = CH4 emissions destroyed by a destruction device other than a flare during the issuance period, in metric tonnes CO2 equivalent;

Q gas cov = Quantity of gas available for destruction during the issuance period, measured at the capture system prior to destruction, in cubic metres at standard conditions;

C CH4 = Average CH4 content in the gas before entering the destruction device during the issuance period, determined in accordance with Part III, in cubic metres of CH4 per cubic metre of gas;

C dest-CH4 = Average CH4 content in the gas leaving the destruction device during the issuance period, determined in accordance with the method in Part V, in cubic metres of CH4 per cubic metre of gas;

0.667 = Density of CH4, in kilograms per cubic metre at standard conditions;

21 = Global Warming Potential factor of CH4;

0.001 = Conversion factor, kilograms to metric tonnes.

Equation 8.1

GHG combustion other = Q gas cov × (C dest-N2O × 1.84 × 310) × 0.001

Where:

GHG combustion other = N2O emissions attributable to combustion of captured gas by a destruction device other than a flare during the issuance period, in metric tonnes CO2 equivalent;

Q gas cov = Quantity of gas available for destruction during the issuance period, measured at the capture system prior to destruction, in cubic metres at standard conditions;

C dest-N2O = Average N2O content in the gas leaving the destruction device during the issuance period, determined in accordance with the method in Part V, in cubic metres of N2O per cubic metre of gas;

1.84 = Density of N2O, in kilograms per cubic metre at standard conditions;

310 = Global Warming Potential factor of N2O;

0.001 = Conversion factor, kilograms to metric tonnes.

(4.2) Calculation method for GHG emissions attributable to fossil fuels

The promoter must calculate, using equation 9, the differential between the GHG emissions for the baseline scenario and the GHG emissions for the project attributable to fossil fuels using equation 9.

If the GHG emissions for the project are above the GHG emissions for the baseline scenario, the latter are subtracted from the reductions in accordance with equation 1. In other cases, the factor “/\GHG fossil” for equation 1 is 0.

Equation 9

Where:

/\GHG fossil = Differential between the GHG emissions for the baseline scenario and the GHG emissions for the project attributable to fossil fuels during the issuance period, in metric tonnes CO2 equivalent;

m = Number of fossil fuels;

j = Fossil fuel;

C project = Quantity of fossil fuel j consumed in the operation of equipment within the project SSRs during the issuance period, expressed

— in kilograms, in the case of fuels whose quantity is expressed as a mass;

— in cubic metres at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in litres, in the case of fuels whose quantity is expressed as a volume of liquid;

C SF = Quantity of fossil fuel j consumed in the operation of equipment within the SSRs included in the baseline scenario during the issuance period, expressed

— in kilograms, in the case of fuels whose quantity is expressed as a mass;

— in cubic metres at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in litres, in the case of fuels whose quantity is expressed as a volume of liquid;

FCO2 = CO2 emission factor for fuel j specified in tables 1-3 to 1-8 of QC.1.7 in Schedule A.2 to the Regulation respecting mandatory reporting of certain emissions of contaminants into the atmosphere (chapter Q-2, r. 15), expressed

— in kilograms of CO2 per kilogram, in the case of fuels whose quantity is expressed as a mass;

— in kilograms of CO2 per cubic metre at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in kilograms of CO2 per litre, in the case of fuels whose quantity is expressed as a volume of liquid;

0.001 = Conversion factor, kilograms to metric tonnes;

FCH4 = CH4 emission factor for fuel j specified in tables 1-3 to 1-8 of QC.1.7 in Schedule A.2 to the Regulation respecting mandatory reporting of certain emissions of contaminants into the atmosphere, expressed

— in grams of CH4 per kilogram, in the case of fuels whose quantity is expressed as a mass;

— in grams of CH4 per cubic metre at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in grams of CH4 per litre, in the case of fuels whose quantity is expressed as a volume of liquid;

0.000001= Conversion factor, grams to metric tonnes;

21 = Global Warming Potential factor of CH4;

FN2O = N2O emission factor for fuel j specified in tables 1-3 to 1-8 of QC.1.7 in Schedule A.2 to the Regulation respecting mandatory reporting of certain emissions of contaminants into the atmosphere, expressed

— in grams of N2O per kilogram, in the case of fuels whose quantity is expressed as a mass;

— in grams of N2O per cubic metre at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in grams of N2O per litre, in the case of fuels whose quantity is expressed as a volume of liquid;

310 = Global Warming Potential factor of N2O.

(5) Data management and project surveillance

(5.1) Data collection

The project promoter is responsible for collecting the information required for project monitoring.

The promoter must show that the data collected at the agricultural operation are actual and properly represent production during the period covered by each project report. The promoter must also keep a livestock raising register for the agricultural operation.

(5.2) Surveillance plan

The promoter must establish a surveillance plan to measure and monitor project parameters in accordance with Figure 5.1:

Figure 5.1. Project surveillance plan

The promoter is responsible for operating the project and monitoring project performance. The promoter must use the CH4 destruction device and the measurement instruments in accordance with the manufacturer’s specifications. The promoter must, in particular, use measurement instruments to measure directly

(1) the flow of gas before being delivered to the destruction device, continuously, recorded every 15 minutes or totalized and recorded at least daily, adjusted for temperature and pressure; and

(2) the CH4 content in the gas entering the destruction device, determined in accordance with the applicable method in Part III;

(3) the CH4 and N2O content in the gas leaving the destruction device, determined in accordance with the applicable method in Part V, when a destruction device other than a flare is used.

The promoter must monitor and document the use of the destruction device at least once per day to ensure the destruction of the CH4. A flare must be equipped with a monitoring device, such as a thermocouple, at its output that certifies correct operation. GHG emission reductions will not be taken into account for the issue of offset credits for periods during which the destruction device is not operating.

When a destruction device or an operation monitoring device, such as a thermocouple on a flare, is not operating, all the CH4 measured as being delivered to the destruction device must be considered as being emitted to the atmosphere during the period of non-operation. The destruction efficiency of the device must be considered to be zero.

(5.3) CH4 and N2O measurement instruments

The promoter must ensure that all gas flow meters and analyzers are

(1) cleaned and inspected on a quarterly basis, except from December to March;

(2) not more than 2 months before the issuance period end date, checked for calibration accuracy by a qualified and independent person, using a portable instrument or manufacturer’s specifications, and ensure that the percentage drift is recorded; and

(3) calibrated by the manufacturer or by a third person certified for that purpose, every 5 years or according to the manufacturer’s specifications, whichever is more frequent.

When a check on a piece of equipment reveals accuracy outside a ± 5% threshold,

(1) the piece of equipment must be calibrated by the manufacturer, or by a third person certified for that purpose by the manufacturer; and

(2) all the data from the meters and analyzers must be scaled according to the following procedure:

(a) the data must be adjusted for the entire period from the last calibration that confirmed accuracy within the ± 5% threshold until such time as the flow meter and analyzer is correctly calibrated; and

(b) the project promoter must estimate the GHG emission reductions using the lesser of the measured flow values without correction and the measured flow values adjusted based on the greatest calibration drift recorded.

The last calibration confirming accuracy within the ± 5% threshold must not have taken place more than 2 months before the end date for the issuance period.

If a portable instrument is used, such as a handheld CH4 analyzer, it must be calibrated at least annually by the manufacturer or by an ISO 17025 accredited laboratory.

(5.4) Data management

The data must be of sufficient quality to meet the calculation requirements and be confirmed by the livestock raising registers of the agricultural operation during the verification.

The project promoter must establish written procedures for each task involving measurements, indicating the person responsible, the frequency and time of the measurements, and the place where the registers are kept.

In addition, the registers must be

(1) legible, dated and revised if needed;

(2) kept in good condition; and

(3) kept in a place that is easily accessible for the duration of the project.

(5.5) Missing data – replacement methods

In situations where data on gas flow rates or CH4 or N2O content are missing, the promoter must apply the data replacement methods set out in Part VI. Missing data on gas flow rates may be replaced only when a continuous analyzer is used to measure CH4 and N2O content. When CH4 and N2O content is measured by sampling, no missing data is permissible.

Part II

Emission factors for the management of manure from livestock

Table 1. CH4 emission factors for the management of manure from dairy and non-dairy cattle

_________________________________________________________________________________
| | |
| Category | CH4 emission factor |
| | Kilograms of CH4 / head / year |
|________________________________________|________________________________________|
| | |
| Dairy cow | 27.8 |
|________________________________________|________________________________________|
| | |
| Dairy heifer | 19.1 |
|________________________________________|________________________________________|
| | |
| Bull | 3.3 |
|________________________________________|________________________________________|
| | |
| Slaughter cow | 3.2 |
|________________________________________|________________________________________|
| | |
| Slaughter heifer | 2.4 |
|________________________________________|________________________________________|
| | |
| Steer | 1.6 |
|________________________________________|________________________________________|
| | |
| Backgrounding cattle | 1.8 |
|________________________________________|________________________________________|
| | |
| Dairy calf or dairy heifer calf | 1.5 |
|________________________________________|________________________________________|

Table 2. CH4 emission factors for the management of manure from other categories of livestock

Part III

Determination of the CH4 content of gas available for burning measured at the capture system before delivery to the flare or other destruction device

When the project is not equipped with a continuous CH4 analyzer, the promoter must sample the gas sent to the destruction device when the device is in operation during the 4 following periods each year:

Sample 1: April – May

Sample 2: June – July

Sample 3: August – September

Sample 4: October – November

To be representative, each sampling must measure concentration, gas flow rate and air temperature during 8 hours, continuously or over several shorter periods. Enough data must be collected to establish a graph of CH4 content as a function of temperature.

The graph will be used to determine CH4 content on days when the gas is not sampled, when the average temperature is known.

The promoter must

(1) sample the gases, measure the gas flow rate and measure the ambient temperature;

(2) produce a graph showing CH4 content as a function of temperature;

(3) determine the average ambient temperature for a given day;

(4) using the graph, determine CH4 content as a function of temperature for each operating period of the destruction device; and

(5) complete the monitoring grid in Part IV.

Part IV

Monitoring grid

_________________________________________________________________________________
| | | | | | |
| Date | Q gaz cov | Ambient | CCH4 | GHG flare | GHG combustion flare |
| | m3 | temperature | in m3 of | or | or |
| | measured | measured in | CH4 per | GHG other | GHG combustion other |
| | | Kelvin | m3 of gas | in CO2 | in CO2 equivalent, |
| | | | | equivalent,| using equation 6 or |
| | | | | using | 8.1 |
| | | | | equation 4 | |
| | | | | or 8 | |
|______|___________|_____________|___________|____________|______________________|
| | | | | | |
|______|___________|_____________|___________|____________|______________________|
| | | | | | |
|______|___________|_____________|___________|____________|______________________|
| | | | | | |
|______|___________|_____________|___________|____________|______________________|
| | | | | | |
|______|___________|_____________|___________|____________|______________________|

Part V

Determination of the CH4 and N2O content of gas leaving a destruction device other than a flare

When the project is not equipped with a continuous CH4 or N2O analyzer, the promoter must sample the available gas leaving the destruction device during the 4 following periods each year:

Sample 1: April – May

Sample 2: June – July

Sample 3: August – September

Sample 4: October – November

The promoter must determine the average CH4 content during the issuance period using equation 10 and the average N2O content using equation 11:

Equation 10

Where:

C dest-CH4 = Average CH4 content of gas leaving the destruction device during the issuance period, in cubic metres of CH4 per cubic metre of gas at standard conditions;

n = Number of samples;

i = Sample;

Cs CH4,i = CH4 content of sample i, measured in the gas leaving the destruction device, in cubic metres of CH4 per cubic metre of gas at standard conditions;

Equation 11

Where:

Cdest-N2O = Average N2O content of gas leaving the destruction system during the issuance period, in cubic metres of N2O per cubic metre of gas at standard conditions;

n = Number of samples;

i = Sample;

Cs N2O,i = N2O content of sample i, measured in the gas leaving the destruction system, in cubic metres of N2O per cubic metre of gas at standard conditions.

Part VI

Missing data – replacement methods

The replacement methods below may be used only

(1) for CH4 or N2O content or gas flow rate parameters;

(2) for data gaps on gas flow rates that are discrete, non-chronic and due to unforeseen circumstances;

(3) when the proper functioning of the destruction device can be shown by reading the thermocouple at the flare or other device;

(4) when data on gas flow rate only, or CH4 or N2O content only, are missing;

(5) to replace data on gas flow rates when a continuous analyzer is used to measure CH4 and N2O content and when it is shown that CH4 and N2O content was consistent with normal operations for the time when the data are missing; and

(6) to replace data on CH4 and N2O content when it is shown that the gas flow rate was consistent with normal operations for the time when the data are missing.

No offset credit may be issued for periods when the replacement methods cannot be used.

PROTOCOL 2

(Replaced, M.O. 2021-06-11, s. 63).

PROTOCOL 3

(Replaced, M.O. 2021-06-11, s. 62).

PROTOCOL 4

ACTIVE COAL MINES – DESTRUCTION OF CH4 FROM A DRAINAGE SYSTEM

Part I

(1) Projects covered

This offset credit protocol covers any project designed to reduce GHG emissions by capturing and destroying CH4 from a CH4 drainage system at an active underground or surface coal mine, except a mountaintop removal mine.

The project must enable the capture and destruction of CH4 that, before the project, was emitted to the atmosphere. The CH4 must be captured within the mine boundaries based on the current mine map and no more than 50 m below the mined seam and, in the case of an underground mine, up to 150 m above that seam. The project must not use CO2, steam or any other fluid or gas to enhance CH4 drainage.

The CH4 must be destroyed on the site of the mine where it was captured using a flare or any other destruction device. Emission reductions following pipeline injection of CH4 are considered as common practice in the operation of an underground mine and are eligible only for a surface mine.

For the purposes of this protocol,

(1) “room and pillar” means a method of underground mining in which approximately half of the coal is left in place as “pillars” to support the roof of the active mining area while “rooms” of coal are extracted;

(2) “coal” means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite under ASTM D388, entitled Standard Classification of Coals by Rank;

(3) “mine gas” means the untreated gas extracted from within a mine through a CH4 drainage system that often contains various levels of other components such as nitrogen, oxygen, CO2 and hydrogen sulfide;

(4) “mine CH4” means the CH4 portion of the mine gas contained in coal seams and surrounding strata that is released as a result of mining operations;

(5) “drainage system” means a system installed in a mine to drain CH4 from coal seams.

(2) First project report

In addition to the information required under the third paragraph of section 70.5 of this Regulation, the first project report must include the following information:

(1) in the case of an underground mine, the mining method employed, such as room and pillar or longwall;

(2) annual coal production, in metric tonnes;

(3) the year of initial mine operation;

(4) the scheduled year of mine closure, if known;

(5) a diagram of the mine site that includes

(a) the location of existing and planned wells and boreholes, specifying whether they were used for premining or post-mining drainage, and whether they are part of the project;

(b) the location of the equipment that will be used to treat or destroy the mine CH4.

(3) Location

The project must be implemented in Canada.

(4) Reduction project SSRs

The reduction project process flowchart in Figure 4.1 and the table in Figure 4.2 show all the SSRs that must be taken into account by the promoter when calculating the GHG emission reductions attributable to the project.

All the SSRs within the dotted line must be counted for the purposes of this protocol.

Figure 4.1. Flowchart for the reduction project process

Figure 4.2. Reduction project SSRs

_________________________________________________________________________________
| | | | | |
| SSR | Description | GHG | Relevant to | Included/|
| # | | | Baseline (B) | Excluded |
| | | | or Project | |
| | | | (P) | |
| | | | | |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 1 | CH4 emissions | CH4 | B, P | Included|
| | from mining activities | | | |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 2 | Emissions from | CO2 | P | Excluded |
| | construction |_________| |__________|
| | and/or | | | |
| | installation of | CH4 | | Excluded |
| | new equipment |_________| |__________|
| | | | | |
| | | N2O | | Excluded |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 3 | Emissions | CO2 | P | Included |
| | resulting from |_________| |__________|
| | fossil fuels | | | |
| | consumed to | CH4 | | Excluded |
| | operate the CH4 |_________| |__________|
| | drainage system | | | |
| | | N2O | | Excluded |
| | | | | |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 4 | Emissions from | CO2 | P | Included |
| | the use of |_________| |__________|
| | supplmental | | | |
| | fossil fuels | CH4 | | Excluded |
| | |_________| |__________|
| | | | | |
| | | N2O | | Excluded |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 5 | Emissions from | CO2 | P | Included |
| | CH4 destruction |_________| |__________|
| | for electricity | | | |
| | generation | N2O | | Excluded |
| |________________________|_________|______________________|__________|
| | | | | |
| | Emissions of | CH4 | P | Included |
| | uncombusted CH4 | | | |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 6 | Emissions from | CO2 | P | Included |
| | CH4 destruction |_________| |__________|
| | for heat | | | |
| | generation | N2O | | Excluded |
| | | | | |
| |________________________|_________|______________________|__________|
| | | | | |
| | Emissions of | CH4 | P | Included |
| | uncombusted CH4 | | | |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 7 | Emissions from | CO2 | P | Included |
| | CH4 destruction |_________| |__________|
| | using a flare or | | | |
| | other device | N2O | | Excluded |
| | | | | |
| |________________________|_________|______________________|__________|
| | | | | |
| | Emissions of | CH4 | P | Included |
| | uncombusted CH4 | | | |
|____________|________________________|_________|______________________|__________|
| | | | | |
| 8 | Pipeline injection | CO2 | P | Excluded |
|(Underground| |_________| |__________|
| mine) | | | | |
| | | N2O | | Excluded |
| | |_________| |__________|
| | | | | |
| | | CH4 | | Excluded |
|____________|________________________|_________|______________________|__________|
| | | | | |
| | Emissions | CO2 | P | Included |
| 8 | resulting from the |_________| |__________|
|(Surface | combustion of | | | |
| mine) | CH4 injected into | N2O | | Excluded |
| | a pipeline | | | |
| |________________________|_________|______________________|__________|
| | | | | |
| | Emissions of | CH4 | P | Included |
| | uncombusted | | | |
| | CH4 injected into | | | |
| | a pipeline | | | |
|____________|________________________|_________|______________________|__________|

(5) Calculation method for the GHG emission reductions attributable to the project

The promoter must calculate the quantity of GHG emission reductions attributable to the project using equation 1:

Equation 1

ER = BE - PE

Where:

ER = GHG emission reductions attributable to the project during the issuance period, in metric tonnes CO2 equivalent;

BE = Emissions under the baseline scenario during the issuance period, calculated using equation 3, in metric tonnes CO2 equivalent;

PE = Project emissions during the issuance period, calculated using equation 5, in metric tonnes CO2 equivalent.

When the flow meter does not correct for the temperature and pressure of the mine gas at standard conditions, the promoter must measure mine pressure and temperature separately and correct the flow values using equation 2. The promoter must use the corrected flow values in all the equations of this protocol.

Equation 2

293.15 P

MGi,t = MGuncorrected × ________ × _______

T 101.325

Where:

MGi,t = Volume of mine gas sent to destruction device i in time interval t, in cubic metres at standard conditions;

i = Destruction device;

t = Time interval shown in the table in Figure 6.1 for which CH4 flow and content measurements are aggregated;

MGuncorrected = Uncorrected volume of mine gas sent to destruction device i in time interval t, in cubic metres;

293.15 = Reference temperature, in Kelvin;

T = Measured temperature of mine gas for the given time period, in Kelvin (°C + 273.15);

P = Pressure of the mine gas for the given time period, in kilopascals;

101.325 = Standard pressure, in kilopascals.

(5.1) Calculation method for GHG emissions in the baseline scenario

In the baseline scenario, CH4 sent to a destruction device during the issuance period, except CH4 captured by a pre-mining surface well used to extract CH4, must be taken into account.

In the case of a surface well used to extract CH4 before a mining operation, CH4 emissions from past periods are considered only during a issuance period when the well is mined through, in other words when one of the following situations occurs:

(1) the well is physically bisected by mining activities;

(2) the well produces elevated amounts of atmospheric gases so that the concentration of nitrogen in the mine gas increases by 5 compared to baseline concentrations according to a gas analysis using a gas chromatograph completed by an ISO 17025 accredited laboratory. To ensure that the elevated nitrogen concentrations are not solely the result of a leak in the well, the oxygen concentration must not have increased by the same proportion as the nitrogen concentration;

(3) in the case of an underground mine, the working face passes less than 150 m below the well;

(4) in the case of an underground mine, the room and pillar method is used and the block of coal that will be left unmined as a pillar is less than 150 m directly below the well.

The promoter must calculate GHG emissions in the baseline scenario using equation 3:

Equation 3

Where:

BE = Baseline scenario emissions during the issuance period, in metric tonnes CO2 equivalent;

n = Number of destruction devices;

i = Destruction device;

Qi = Total quantity of CH4 sent to destruction device i during the issuance period, calculated using equation 4, in cubic metres of CH4 at standard conditions;

0.667 = Density of CH4, in kilograms of CH4 per cubic metre of CH4 at standard conditions;

0.001 = Conversion factor, kilograms to metric tonnes;

21 = Global Warming Potential factor of CH4;

Equation 4

Where:

Qi = Total quantity of CH4 sent to destruction device i during the issuance period, in cubic metres of CH4 at standard conditions;

n = Number of time intervals during the issuance period;

t = Time interval shown in the table in Figure 6.1 for which CH4 flow and content measurements for the mine gas are aggregated;

MGi,t = Volume of mine gas sent to destruction device i in time interval t, in cubic metres at standard conditions, except mine gas from a surface well that is not yet mined through. Despite the foregoing, if the surface well is mined through during the issuance period, the mine gas sent to a destruction device during the current reporting period and in previous years must be included;

CCH4,t = Average CH4 content in the mine gas sent to a destruction device during time interval t, in cubic metres of CH4 per cubic metre of mine gas.

(5.2) Calculation method for GHG project emissions

The promoter must calculate the GHG project emissions using equations 5 to 8. The CO2 emissions attributable to the destruction of CH4 from a pre-mining surface well used to extract CH4 during a current issuance period, calculated using equation 7, must be included even if the well has not yet been mined through.

Equation 5

PE = FFCO2 + DMCO2 + UMCH4

Where:

PE = Project emissions during the issuance period, in metric tonnes CO2 equivalent;

FFCO2 = Total CO2 emissions attributable to the consumption of fossil fuel to capture and destroy mine CH4 during the issuance period, calculated using equation 6, in metric tonnes CO2 equivalent;

DMCO2 = Total CO2 attributable to the destruction of CH4 during the issuance period, calculated using equation 7, in metric tonnes CO2 equivalent;

UMCH4 = CH4 emissions attributable to uncombusted CH4 during a issuance period, calculated using equation 8, in metric tonnes CO2 equivalent;

Equation 6

Where:

FFCO2 = Total CO2 attributable to the consumption of fossil fuel to capture and destroy mine CH4 during the issuance period, in metric tonnes CO2 equivalent;

n = Number of types of fossil fuel;

j = Type of fossil fuel;

FFPR,j = Total quantity of fossil fuel j consumed, expressed

— in kilograms, in the case of fuels whose quantity is expressed as a mass;

— in cubic metres at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in litres, in the case of fuels whose quantity is expressed as a volume of liquid;

EFCF,j = CO2 emission factor for fossil fuel j specified in tables 1-3 to 1-8 of QC.1.7 in Schedule A.2 to the Regulation respecting mandatory reporting of certain emissions of contaminants into the atmosphere (chapter Q-2, r. 15), expressed

— in kilograms of CO2 per kilogram, in the case of fuels whose quantity is expressed as a mass;

— in kilograms of CO2 per cubic metre at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in kilograms of CO2 per litre, in the case of fuels whose quantity is expressed as a volume of liquid;

1,000 = Conversion factor, metric tonnes to kilograms;

Equation 7

Where:

DMCO2 = Total CO2 attributable to the destruction of CH4 during a issuance period, in metric tonnes CO2 equivalent;

n = Number of destruction devices;

i = Destruction device;

Qi = Total quantity of CH4 sent to destruction device i during the issuance period, calculated using equation 4, in cubic metres of CH4 at standard conditions;

DEi = Default CH4 destruction efficiency of destruction device i, determined in accordance with Part II;

1.556 = CO2 emission factor attributable to the combustion of CH4, in kilograms of CO2 per cubic metre of CH4 combusted;

0.001 = Conversion factor, kilograms to metric tonnes;

Equation 8

Where:

UMCH4 = CH4 emissions attributable to uncombusted CH4 during the issuance period, in metric tonnes CO2 equivalent;

n = Number of destruction devices;

i = Destruction device;

Qi = Total quantity of CH4 sent to destruction device i during the issuance period, calculated using equation 4, in cubic metres of CH4 at standard conditions;

DEi = Default CH4 destruction efficiency of destruction device i, determined in accordance with Part II;

0.667 = Density of CH4, in kilograms of CH4 per cubic metre of CH4 at standard conditions;

0.001 = Conversion factor, kilograms to metric tonnes;

21 = Global Warming Potential factor of CH4.

(6) Project surveillance

(6.1) Data collection

The promoter is responsible for collecting the information required for project monitoring.

The promoter must show that the data collected are actual and that rigorous supervision and record-keeping procedures are applied at the project site.

(6.2) Surveillance plan

The promoter must establish a surveillance plan to measure and monitor project parameters in accordance with Figure 6.1:

Figure 6.1. Project surveillance plan

The surveillance plan must

(1) specify the methods used to collect and record the data required for all the relevant parameters in the table in Figure 6.1;

(2) specify

(a) the frequency of data acquisition;

(b) the frequency of instrument cleaning, inspection and calibration activities, and of the verification of instrument calibration accuracy; and

(c) the role of the person responsible for each monitoring activity, as well as the quality assurance and quality control measures taken to ensure that data acquisition and instrument calibration are carried out consistently and with precision; and

(3) contain a detailed diagram of the mine gas capture and destruction system, including the placement of all measurement instruments and equipment that affect included SSRs.

The promoter is responsible for carrying out and monitoring project performance. The promoter must use the mine gas destruction device and the measurement instruments in accordance with the manufacturer’s specifications. The promoter must, in particular, use measurement instruments to measure directly

(1) the flow of mine gas sent to each destruction device, continuously, recorded every 15 minutes and totalized as a daily average, adjusted for temperature and pressure;

(2) the CH4 content of the mine gas sent to each destruction device, continuously, recorded every 15 minutes and totalized as a daily average.

When temperature and pressure must be measured to correct flow values at standard conditions, the parameters must be measured at least hourly.

The operating status of the mine gas destruction device must be monitored and recorded at least hourly.

For every destruction device, the promoter must show, in the first project report, that a monitoring device has been installed to verify the operation of each destruction device. The promoter must also show, in each subsequent project report, that the monitoring device has operated correctly.

GHG emission reductions will not be taken into account for the issue of offset credits for periods during which the destruction device or the monitoring device for the operation of the destruction device is not operating.

(6.3) Measurement instruments

The promoter must ensure that all mine gas flow meters and CH4 analyzers are

(1) cleaned and inspected as specified in the project’s surveillance plan and at the minimum cleaning and inspection frequency specified by the manufacturer, with all cleaning and inspection activities documented by personnel;

(2) not more than 2 months before or after the issuance period end date, either

(a) checked for calibration accuracy by a qualified and independent person, using a portable instrument, such as a pitot tube, or in accordance with the manufacturer’s specifications, and ensure that the percentage drift is recorded; or

(b) calibrated by the manufacturer or by a third person certified for that purpose by the manufacturer; and

(3) calibrated by the manufacturer or by a third person certified for that purpose by the manufacturer or every 5 years, whichever is more frequent.

A calibration certificate or a verification report on calibration accuracy must be produced and included in the project report. The verification provided for in section 70.16 of this Regulation must include confirmation that the person is qualified to verify calibration accuracy.

Flow meter calibrations must be documented to show that the meter was calibrated to a range of flow rates corresponding to the flow rates expected for the drainage system.

CH4 analyzer calibrations must be documented to show that the calibration was carried out to a range of temperature and pressure conditions corresponding to the range of conditions measured for the drainage system.

The verification of flow meter and analyzer calibration accuracy must show that the instruments provide a reading of volumetric flow or CH4 content that is within a +/-5% accuracy threshold.

When a verification of the calibration accuracy of a device shows a shift outside the +/-5% accuracy threshold, the device must be calibrated by the manufacturer or by a third person certified for that purpose by the manufacturer. In addition, for the entire period from the last calibration that confirmed accuracy within the ± 5% threshold until such time as the piece of equipment is correctly calibrated, the promoter must use the more conservative of

(1) the measured values without correction;

(2) the adjusted values based on the greatest calibration drift recorded at the time of calibration.

The last calibration confirming accuracy within the ± 5% threshold must not have taken place more than 2 months before the end date for the issuance period.

No offset credit may be issued for a issuance period when the calibration or verification of the calibration accuracy of the required instruments has not been correctly carried out and documented.

(6.4) Data management

Information on data procedures and data monitoring must be managed in a way that guarantees the integrity, exhaustiveness, accuracy and validity of the data.

The promoter must keep the following documents and information:

(1) the information required under the surveillance plan;

(2) information on each flow meter, CH4 analyzer and destruction device used, including type, their model number, serial number and manufacturer’s maintenance and calibration procedures;

(3) the calibration date, time and results for CH4 analyzers and flow meters, and the corrective measures applied if a piece of equipment fails to meet the requirements of this Regulation;

(4) the maintenance records for capture, destruction and monitoring systems;

(5) operating records showing annual coal production.

(6.5) Missing data – replacement methods

In situations where data on flow rates or CH4 content are missing, the promoter must apply the data replacement methods set out in Part III.

Part II

Destruction efficiencies for destruction devices

The promoter must use the destruction efficiency shown in Table 1 for the project destruction device.

Table 1. Default destruction efficiencies for destruction devices

__________________________________________________________________________________
| | |
| Destruction device | Efficiency |
|____________________________________________|_____________________________________|
| | |
| Open flare | 0.96 |
|____________________________________________|_____________________________________|
| | |
| Enclosed flare | 0.995 |
|____________________________________________|_____________________________________|
| | |
| Internal combustion engine | 0.936 |
|____________________________________________|_____________________________________|
| | |
| Boiler | 0.98 |
|____________________________________________|_____________________________________|
| | |
| Microturbine or large gas turbine | 0.995 |
|____________________________________________|_____________________________________|
| | |
| Upgrade and injection into a pipeline | 0.96 |
| (surface mine) | |
|____________________________________________|_____________________________________|

Part III

Missing data – replacement methods

The replacement methods below may be used only

(1) for missing mine gas flow rate or CH4 content parameters;

(2) for missing data that are discrete, non-chronic and due to unforeseen circumstances;

(3) when the proper functioning of the destruction device can be shown by thermocouple readings at the flare or at the other devices of the same nature;

(4) to replace data on mine gas flow rates when it is shown that CH4 content was consistent with normal operations for the time when the data are missing; and

(5) to replace data on CH4 content when it is shown that the mine gas flow rate was consistent with normal operations for the time when the data are missing.

No offset credit may be issued for periods when the replacement methods cannot be used.

PROTOCOL 5

ACTIVE UNDERGROUND COAL MINES – DESTRUCTION OF CH4 FROM VENTILATION AIR

Part I

(1) Projects covered

This offset credit protocol covers any project designed to reduce GHG emissions by capturing and destroying CH4 from the ventilation system of an active underground coal mine.

The project must enable the capture and destruction of CH4 that, before the project, was emitted to the atmosphere. The CH4 must be captured within the mine boundaries based on the current mine map and must be destroyed on the site of the mine where it was captured using a destruction device.

For the purposes of this protocol,

(1) “ventilation air” means air from a mine ventilation system;

(2) “coal” means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite under ASTM D388, entitled Standard Classification of Coals by Rank;

(3) “ventilation air CH4” means the CH4 contained in ventilation air.

(2) First project report

In addition to the information required under the third paragraph of section 70.5 of this Regulation, the first project report must include the following information:

(1) the mining method employed, such as room and pillar or longwall;

(2) annual coal production;

(3) the year of initial mine operation;

(4) the scheduled year of mine closure, if known;

(5) a diagram of the mine site that includes

(a) the location of existing and planned ventilation shafts, specifying whether they are part of the project;

(b) the location of the equipment that will be used to treat or destroy ventilation air CH4.

(3) Location

The project must be implemented in Canada.

(4) Reduction project SSRs

All the SSRs within the dotted line must be counted for the purposes of this protocol.

Figure 4.1. Flowchart for the reduction project process

Figure 4.2. Reduction project SSRs

(5) Calculation method for the GHG emission reductions attributable to the project

The promoter must calculate the quantity of GHG emission reductions attributable to the project using equation 1:

Equation 1

ER = BE - PE

Where:

ER = GHG emission reductions attributable to the project during the issuance period, in metric tonnes CO2 equivalent;

BE = Emissions under the baseline scenario during the issuance period, calculated using equation 2, in metric tonnes CO2 equivalent;

PE = Project emissions during the issuance period, calculated using equation 3, in metric tonnes CO2 equivalent.

(5.1) Calculation method for GHG emissions in the baseline scenario

The promoter must calculate GHG emissions in the baseline scenario using equation 2:

Equation 2

Where:

BE = Baseline scenario emissions during the issuance period, in metric tonnes CO2 equivalent;

n = Number of time intervals during the issuance period;

t = Time interval shown in the table in Figure 6.1 for which flow and content measurements of ventilation air CH4 are aggregated;

VAEt = Volume of ventilation air sent to destruction device during time interval t, in cubic metres at standard conditions;

CCH4,t = Average CH4 content in ventilation air before entering destruction device during time interval t, in cubic metres of CH4 per cubic metre of ventilation air;

0.667 = Density of CH4, in kilograms of CH4 per cubic metre of CH4 at standard conditions;

0.001 = Conversion factor, kilograms to metric tonnes;

21 = Global Warming Potential factor of CH4.

If a mass flow meter is used to monitor gas flow instead of a volumetric flow meter, the volume and density terms must be replaced by the monitored mass value in kilograms. The CH4 content must be in mass percent.

(5.2) Calculation method for GHG project emissions

The promoter must calculate the GHG project emissions using equations 3 to 7:

Equation 3

PE = FFCO2 + DMCO2 + UMCH4

Where:

PE = Project emissions during a issuance period, in metric tonnes CO2 equivalent;

FFCO2 = Total CO2 attributable to the consumption of fossil fuel to capture and destroy ventilation air CH4 during a issuance period, calculated using equation 4, in metric tonnes CO2 equivalent;

DMCO2 = Total CO2 attributable to the destruction of CH4 during a issuance period, calculated using equation 6, in metric tonnes CO2 equivalent;

UMCH4 = CH4 emissions attributable to uncombusted CH4 during a issuance period, calculated using equation 7, in metric tonnes CO2 equivalent;

Equation 4

Where:

FFCO2 = Total CO2 attributable to the consumption of fossil fuel to capture and destroy ventilation air CH4 during a issuance period, in metric tonnes CO2 equivalent;

n = Number of types of fossil fuel;

j = Type of fossil fuel;

FFPR,j = Annual quantity of fossil fuel j consumed, expressed

— in kilograms, in the case of fuels whose quantity is expressed as a mass;

— in cubic metres at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in litres, in the case of fuels whose quantity is expressed as a volume of liquid;

EFFF,j = CO2 emission factor for fossil fuel j specified in tables 1-3 to 1-8 of QC.1.7 in Schedule A.2 to the Regulation respecting mandatory reporting of certain emissions of contaminants into the atmosphere (chapter Q-2, r. 15), expressed

— in kilograms of CO2 per kilogram, in the case of fuels whose quantity is expressed as a mass;

— in kilograms of CO2 per cubic metre at standard conditions, in the case of fuels whose quantity is expressed as a volume of gas;

— in kilograms of CO2 per litre, in the case of fuels whose quantity is expressed as a volume of liquid;

1,000 = Conversion factor, metric tonnes to kilograms;

If the volume of ventilation air leaving the destruction device is not measured as specified in Figure 6.1, it must be calculated using equation 5:

Equation 5

VAS = VAE + CA

Where:

VAS = Volume of ventilation air leaving the destruction device during the issuance period, in cubic metres at standard conditions;

VAE = Volume of ventilation air sent to a destruction device during the issuance period, in cubic metres at standard conditions;

CA = Volume of cooling air added after the point of metering for the volume of ventilation air sent to the destruction device (VAE), in cubic metres at standard conditions, or a value of 0 if no cooling air is added;

Equation 6

DMCO2 = [(VAE × CCH4) - (VAS × Cdest-CH4)] × 1.556 × 0.001

Where:

DMCO2 = Total CO2 attributable to the destruction of CH4 during a issuance period, in metric tonnes CO2 equivalent;

VAE = Volume of ventilation air sent to a destruction device during the issuance period, in cubic metres at standard conditions;

VAS = Volume of ventilation air leaving the destruction device during the issuance period, in cubic metres at standard conditions;

CCH4 = Average CH4 content in ventilation air before entering destruction device during the issuance period, in cubic metres of CH4 per cubic metre of gas;

Cdest-CH4 = Average CH4 content in ventilation air leaving the destruction device during the issuance period, in cubic metres of CH4 per cubic metre of gas;

1.556 = CO2 emission factor attributable to the combustion of CH4, in kilograms of CO2 per cubic metre of CH4 combusted;

0.001 = Conversion factor, kilograms to metric tonnes;

Equation 7

UMCH4 = VAS × Tdest-CH4 × 0.667 × 0.001 × 21

Where:

UMCH4 = CH4 emissions attributable to uncombusted CH4 during a issuance period, in metric tonnes CO2 equivalent;

VAS = Volume of ventilation air leaving the destruction device during the issuance period, in cubic metres at standard conditions;

Tdest-CH4 = Average CH4 content in ventilation air leaving the destruction device during the issuance period, in cubic metres of CH4 per cubic metre of gas;

0.667 = Density of CH4, in kilograms of CH4 per cubic metre of CH4 at standard conditions;

0.001 = Conversion factor, kilograms to metric tonnes;

21 = Global Warming Potential factor of CH4.

(6) Project surveillance

(6.1) Data collection

The promoter is responsible for collecting the information required for project monitoring.

The promoter must show that the data collected are actual and that rigorous supervision and record-keeping procedures are applied at the project site.

(6.2) Surveillance plan

The promoter must establish a surveillance plan to measure and monitor project parameters in accordance with Figure 6.1:

Figure 6.1. Project surveillance plan

The surveillance plan must

(1) specify the methods used to collect and record the data required for all the relevant parameters in the table in Figure 6.1;

(2) specify

(a) the frequency of data acquisition;

(b) the frequency of instrument cleaning, inspection and calibration activities, and of the verification of instrument calibration accuracy; and

(3) contain a detailed diagram of the ventilation air capture and destruction system, including the placement of all measurement instruments and equipment that affect included SSRs.

The promoter is responsible for carrying out and monitoring project performance. The promoter must use the destruction device for ventilation air CH4 and the measurement instruments in accordance with the manufacturer’s specifications. The promoter must, in particular, use measurement instruments to measure directly

(1) the flow of ventilation air sent to each destruction device, continuously, recorded every 2 minutes and totalized as an hourly average adjusted for temperature and pressure;

(2) the CH4 content of ventilation air sent to each destruction device, continuously, recorded every 2 minutes and totalized as an hourly average.

When temperature and pressure must be measured to correct flow values at standard conditions, the parameters must be measured at least hourly.

The operating status of destruction device of ventilation air must be monitored and recorded at least hourly.

For every destruction device, the promoter must show in the first project report that a monitoring device has been installed to verify the operation of each destruction device. The promoter must also show in each project report that the monitoring device has operated correctly.

(6.3) Measurement instruments

The promoter must ensure that all ventilation gas flow meters and CH4 analyzers are

(2) not more than 2 months before or after the issuance period end date, either

(a) checked for calibration accuracy by a qualified and independent person, using a portable instrument, such as a pitot tube, or the manufacturer’s specifications, and ensure that the percentage drift is recorded. The CH4 analyzer must be checked using gas with a CH4 content of less than 2%;

(b) calibrated by the manufacturer or by a third person certified for that purpose by the manufacturer; and

(3) calibrated by the manufacturer or by a third person certified for that purpose by the manufacturer, according to the manufacturer’s specifications or every 5 years, whichever is more frequent.

Flow meter calibrations must be documented to show that the meter was calibrated to a range of flow rates corresponding to the flow rates expected for the ventilation system.

CH4 analyzer calibrations must be documented to show that the calibration was carried out to a range of temperature, pressure and content conditions corresponding to the range of conditions measured for the mine.

The verification of flow meter and analyzer calibration accuracy must show that the instrument provides a reading of volumetric flow or CH4 content that is within a +/-5% accuracy threshold.

(1) the measured values without correction;

(2) the adjusted values based on the greatest calibration drift recorded at the time of calibration.

The last calibration confirming accuracy within the ± 5% threshold must not have taken place more than 2 months before the end date for the issuance period.

No offset credit may be issued for a issuance period when the calibration or verification of the calibration accuracy of the required instruments has not been correctly carried out and documented.

(6.4) Data management

Information on data procedures and data monitoring must be managed in a way that guarantees the integrity, exhaustiveness, accuracy and validity of the data.

The promoter must keep the following documents and information:

(1) the information required under the surveillance plan;

(2) information on each flow meter, CH4 analyzer and destruction device used, including type, their model number, serial number and manufacturer’s maintenance and calibration procedures;

(3) the calibration date, time and results for CH4 analyzers and flow meters, and the corrective measures applied if a piece of equipment fails to meet the requirements of this Regulation;

(4) the maintenance records for capture, destruction and monitoring systems;

(5) operating records showing annual coal production.

(6.5) Missing data – replacement methods

In situations where data on flow rates or CH4 content are missing, the promoter must apply the data replacement methods set out in Part II.

Part II

Missing data – replacement methods

The replacement methods below may be used only

(1) for missing ventilation gas flow rate or CH4 content parameters;

(2) for missing data that are discrete, non-chronic and due to unforeseen circumstances;

(3) when the proper functioning of the destruction device can be shown by thermocouple readings or other devices of the same nature;

(4) to replace data on ventilation gas flow rates when it is shown that CH4 content was consistent with normal operations for the time when the data are missing; and

(5) to replace data on CH4 content when it is shown that the ventilation gas flow rate was consistent with normal operations for the time when the data are missing.

No offset credit may be issued for periods when the replacement methods cannot be used.

O.C. 1184-2012, s. 52; O.C. 1138-2013, s. 29; O.C. 902-2014, ss. 66, 67 and 68; O.C. 1089-2015, s. 31; O.C. 1125-2017, ss. 64 and 65; 2021-06-11M.O. 2021-06-11, s. 621; 2021-06-11M.O. 2021-06-11, s. 631.

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