This Appendix is deemed to be a regulation of the Minister made under the second paragraph of section 46.8 of the Envrironment 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
_________________________________________________________________________________
| | | | | |
| SSR | Description | GHG | Relevant to | Included |
| # | | | project | or |
| | | | baseline | Excluded |
| | | | scenario (B)| |
| | | | and/or | |
| | | | Project (P) | |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 1 | Enteric fermentation | CH4 | B, P | Excluded |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 2 | Manure collection | CH4 | | Excluded |
| | | CO2 | B, P | Excluded |
| | | N2O | | Excluded |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 3 | Manure storage | CH4 | | Included |
| | | CO2 | B, P | Excluded |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 4 | Manure transportation | CH4 | | Excluded |
| | | CO2 | B, P | Excluded |
| | | N2O | | Excluded |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 5 | Manure spreading | CH4 | | Excluded |
| | | CO2 | B, P | Excluded |
| | | N2O | | Excluded |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 6 | Flare | CH4 | | Included |
| | | CO2 | P | Excluded |
| | | N2O | | Included |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 7 | Other CH4 destruction device | CH4 | | Included |
| | | CO2 | P | Excluded |
| | | N2O | | Included |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 8 | Construction of project facilities | CH4 | | Excluded |
| | | CO2 | P | Excluded |
| | | N2O | | Excluded |
|_____|__________________________________________|_______|_____________|__________|
| | | | | |
| 9 | Equipment using fossil fuel | CH4 | | Included |
| | | CO2 | B, P | Included |
| | | N2O | | Included |
|_____|__________________________________________|_______|_____________|__________|
(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 project reporting period, in metric tonnes CO2 equivalent;
GHG project = Gross reduction in GHG emissions from the project during the project reporting 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 project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
GHG dest flare = Lesser of the CH4 emissions destroyed at flare during the project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
n = Number of days on which gas is produced during the project reporting 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 project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
n = Number of days on which gas is produced during the project reporting 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 project reporting 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 project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
Q gas cov = Quantity of gas available for destruction during the project reporting 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 project reporting 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 project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
Q gas cov = Quantity of gas available for destruction during the project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting 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
_________________________________________________________________________________
| | | | | |
|Parameter |Factor used|Unit of |Method |Frequency of |
| |in the |measurement | |measurement |
| |equations | | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|Average annual |Nb |Head |Livestock |At each project |
|population of | | |raising |reporting period |
|each category | | |register | |
|of livestock | | | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|Outdoor |N/A |Degree Kelvin |As measured, or|Daily average |
|temperature | | |according to | |
| | | |Environment | |
| | | |Canada | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|Quantity of gas |Q gas cov |Cubic metre |Flow meter |At each project |
|available for | | | |reporting period |
|destruction | | | |(sum of daily |
|during the | | | |readings) |
|project reporting| | | | |
|period | | | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|CH4 content |C CH4 |Cubic metre of |Sample and |Quarterly, in |
|between the | |CH4 per cubic |analysis |accordance with |
|manure storage | |metre of gas at | |Part III |
|facility and the | |standard | | |
|destruction | |conditions | | |
|device | | | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|CH4 content |C dest-CH4 |Cubic metre of |Sample and |Quarterly, in |
|leaving the | |CH4 per cubic |analysis |accordance with |
|destruction | |metre of gas at | |Part V |
|device (other | |standard | | |
|than a flare) | |conditions | | |
| | | | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|N2O content |C dest-N2O |Cubic metre of |Sample and |Quarterly, in |
|leaving the | |N2O per cubic |analysis |accordance with |
|destruction | |metre of gas at | |Part V |
|device (other | |standard | | |
|than a flare) | |conditions | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|Quantity of |C project |Kilogram (solid)|Purchase |At each project |
|fossil fuel used | | |invoices |reporting period |
|to operate | |Cubic metre | | |
|equipment within | |(gas) | | |
|the project SSRs | | | | |
|during the | |Litres (liquid) | | |
|project reporting| | | | |
|period | | | | |
|_________________|___________|________________|_______________|__________________|
| | | | | |
|Quantity of |C SF |Kilogram (solid)|Purchase |At each project |
|fossil fuel used | | |invoices |reporting period |
|to operate | |Cubic metre | | |
|equipment within | |(gas) | | |
|the project SSRs | | | | |
|for the baseline | |Litres (liquid) | | |
|scenario, during | | | | |
|the project | | | | |
|reporting period | | | | |
|_________________|___________|________________|_______________|__________________|
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 project reporting 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 project reporting 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
_________________________________________________________________________________
| | |
| Category | CH4 emission factor |
| | Kilograms of CH4 / head / year |
|________________________________________|________________________________________|
| | |
| Piglet | 1.66 |
|________________________________________|________________________________________|
| | |
| Hog | 6.48 |
|________________________________________|________________________________________|
| | |
| Sow | 7.71 |
|________________________________________|________________________________________|
| | |
| Boar | 6.40 |
|________________________________________|________________________________________|
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 project reporting 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 project reporting 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 project reporting 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.
_________________________________________________________________________________
| | |
| Missing data period | Replacement method |
|_______________________________|_________________________________________________|
| | |
| Less than 6 hours | Use the average of the 4 hours immediately |
| | before and following the missing data period |
|_______________________________|_________________________________________________|
| | |
| 6 to less than 24 hour | Use the 90% lower or upper confidence limit of |
| | the 24 hours prior to and after the missing |
| | data period, whichever results in greater |
| | conservativeness |
|_______________________________|_________________________________________________|
| | |
| 1 to 7 days | Use the 95% lower or upper confidence limit of |
| | the 72 hours prior to and after the missing |
| | data period, whichever results in greater |
| | conservativeness |
|_______________________________|_________________________________________________|
| | |
| More than 7 days | No data may be replaced and no reduction may |
| | be credited |
|_______________________________|_________________________________________________|
PROTOCOL 2
LANDFILL SITES – CH4 TREATMENT OR DESTRUCTION
Part I
(1) Projects covered
This offset credit protocol covers any project designed to reduce GHG emissions by treating or destroying the CH4 captured in a landfill site in Québec.
The project must involve the use of an eligible device to treat or destroy CH4 captured at a landfill site that meets the following conditions at the time of registration:
(1) on the date of application for registration and for the entire duration of the project, if the site is in operation, it receives less than 50,000 metric tonnes of residual materials annually and has a capacity of less than 1.5 million cubic metres;
(2) on the date of application for registration, in every case, the site has less than 450,000 metric tonnes of residual materials in place, or the CH4 captured from the LFG has a heat capacity of less than 3 GJ/h.
Eligible treatment or destruction devices are enclosed flares, open flares, combustion engines, boilers, turbines and CH4 liquefaction units.
The project must capture and treat or destroy CH4 that, before the project, was emitted to the atmosphere. The CH4 may be treated or destroyed on the landfill site or transported and treated or destroyed off-site.
For the purposes of this protocol,
(1) “landfill gas” (LFG) means any gas resulting from the decomposition of residual materials disposed of at a landfill site;
(2) “landfill site” means a place where residual materials is permanently disposed of above or below ground.
The provisions of subparagraph 1 of the second paragraph of this Division and those of Division 1.2 do not apply to a landfill site of a pulp and paper mill, a sawmill or an oriented strandboard manufacturing plant.
(1.1) (Revoked).
(1.2) Landfill site that is closed on the date of application for registration
In the case of a landfill site that is closed on the date of application for registration,
(1) (subparagraph revoked);
(2) if the site opened or was extended between 2006 and 2008 inclusively, it should have received less than 50,000 tonnes of residual materials annually and should have had a maximum capacity of less than 1,500,000 cubic metres; and
(3) if the site was in operation in 2009 or a subsequent year, the site should have received less than 50,000 metric tonnes of residual materials annually and should have had a maximum capacity of less than 1,500,000 cubic metres.
(2) Location
The project must be carried out within the borders of the province of Québec.
(3) Calculation of CH4 heat capacity captured from the landfill site
When a site has over 450,000 tonnes of residual materials in place, the promoter must assess the heat capacity of the CH4 captured, in gigajoules per hour, using the following method:
(1) by calculating the quantity of CH4 emitted each hour;
(2) by determining the quantity of CH4 captured each hour by multiplying the quantity of CH4 emitted each hour by 0.75;
(3) by determining the heat capacity by multiplying the quantity of CH4 captured each hour by the high heat value of the LFG of the portion of the CH4 set out in table 1.1 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).
The promoter must assess the quantity of CH4 emitted by the landfill site pursuant to Division 3 using the following method:
(1) by determining the quantity of CH4 generated using the Landgem software of the U.S. Environmental Protection Agency (USEPA), available at http://www.epa.gov/ttncatc1/products.html#software;
(2) by determining the quantity of residual materials disposed of annually using the data available since the opening of the landfill site;
(3) by using, for the parameters “k” and “Lo” of the software referred to in paragraph 1, the most recent parameters from the national inventory report on GHG emissions prepared by Environment Canada;
(4) by using a percentage of 50% as the percentage of CH4 in LFG;
(5) by using a value of 0.667 kg per cubic metre at standard conditions as the density of CH4.
(4) Additionnality
For the purposes of subparagraph b of paragraph 6 of section 70.3 of this Regulation, the project is considered to go beyond current practice when it meets the conditions in Divisions 1 to 3.
(5) Reduction project SSRs
The reduction project process flowchart in Figure 5.1 and the table in Figure 5.2 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 5.1. Flowchart for the reduction project process
Figure 5.2. Reduction project SSRs
_________________________________________________________________________________
| | | | | |
| SSR | Description | GHG | Relevant to | Included |
| # | | | project | or |
| | | | baseline | Excluded |
| | | | scenario (B)| |
| | | | and/or | |
| | | | Project (P) | |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 1 | Residual materials generation | N/A | B, P | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 2 | Residual materials collection | CO2 | B, P | Excluded |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Excluded |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 3 | Residual materials placing activities | CO2 | B, P | Excluded |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Excluded |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 4 | Decomposition of residual materials in | CO2 | B, P | Excluded |
| | landfill |_____| |__________|
| | | | | |
| | | CH4 | | Included |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 5 | LFG capture system | CO2 | P | Included |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Excluded |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 6 | Supplemental fuel | CO2 | P | Included |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Included |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 7 | LFG boiler destruction | CO2 | P | Excluded |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Included |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 8 | Electricity generation from LFG | CO2 | P | Excluded |
| | (combustion engine, turbine, fuel cell) |_____| |__________|
| | | | | |
| | | CH4 | | Included |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 9 | LFG flare destruction | CO2 | P | Excluded |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Included |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 10 | LFG upgrading | CO2 | P | Included |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Excluded |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 11 | Boiler following injection into a pipeline| CO2 | P | Excluded |
| | |_____| |__________|
| | | | | |
| | | CH4 | | Included |
| | |_____| |__________|
| | | | | |
| | | N2O | | Excluded |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 12 | Avoided emissions from use of landfill | CO2 | P | Excluded |
| | gas project-generated thermal energy to | | | |
| | replace energy from a fossil fuel | | | |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 13 | Avoided emissions from use of | CO2 | P | Excluded |
| | project-generated electricity to replace | | | |
| | energy from a fossil fuel | | | |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 14 | Avoided emissions from use | CO2 | P | Excluded |
| | of natural gas energy to | | | |
| | replace energy from a fossil fuel | | | |
|______|___________________________________________|_____|_____________|__________|
| | | | | |
| 15 | Liquefaction of LFG and use | CO2 | P | Excluded |
| | as liquefied natural gas |_____| |__________|
| | | | | |
| | | CH4 | | Included |
| | |_____| |__________|
| | | | | |
| | | N2O | | Included |
|______|___________________________________________|_____|_____________|__________|
(6) Calculation method for the GHG emission reductions attributable to the project
The promoter must calculate 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 project reporting period, in metric tonnes CO2 equivalent;
BE = Baseline scenario emissions during the project reporting period, calculated using equation 3, in metric tonnes CO2 equivalent;
PE = Project emissions during the project reporting period, calculated using equation 7, in metric tonnes CO2 equivalent.
When the flow meter does not correct for the temperature and pressure of the LFG at standard conditions, the promoter must measure LFG 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
293.13 P
LFGi,t = LFGuncorrected × ________ ×_________
T 101.325
Where:
LFGi,t = Corrected volume of LFG sent to treatment or destruction device i in time interval t, in cubic metres at standard conditions;
i = Treatment or destruction device;
t = Time interval shown in the table in Figure 7.1 for which CH4 flow and content measurements are aggregated;
LFGuncorrected = Uncorrected volume of LFG captured for the given time interval, in actual cubic metres;
T = Measured temperature of LFG for the given time period, in Kelvin (°C + 273.15);
P = Measured pressure of the LFG for the given time interval, in kilopascals.
(6.1) Calculation method for GHG emissions in the baseline scenario
The promoter must calculate GHG emissions in the baseline scenario using equations 3 to 6.
For that purpose, the promoter must
(1) for landfill sites with a geomembrane covering the entire landfill area, use a CH4 oxidation rate of zero (0%). In this case, the promoter must show in the first project report that the landfill site has a geomembrane that meets the requirements of the Regulation respecting the landfilling and incineration of residual materials(chapter Q-2, r. 19); and
(2) for all other landfill sites, use a CH4 oxidation factor of 10%.
Equation 3
BE = (CH4DESTPR) × 21 × (1 - OX) × (1 - DF)
Where:
BE = Baseline scenario emissions during the project reporting period, in metric tonnes CO2 equivalent;
CH4DestPR = Total quantity of CH4 treated or destroyed by all LFG treatment and destruction devices during the project reporting period, calculated using equation 4, in metric tonnes of CH4;
21 = Global Warming Potential factor of CH4;
OX = Factor for the oxidation of CH4 by soil bacteria, namely a factor of 0 for landfill sites with a geomembrane covering the entire landfill area, or a factor of 0.10 in other cases;
DF = Discount factor to account for uncertainties associated with the monitoring equipment for CH4 content in the LFG, namely a factor of 0 when the CH4 content in the LFG is measured continuously, and 0.1 in other cases, with measurements made at least weekly;
Equation 4
Where:
CH4DestPR = Total quantity of CH4 treated or destroyed by all LFG treatment or destruction devices during the project reporting period, in metric tonnes of CH4;
n = Number of treatment or destruction devices;
i = Treatment or destruction device;
CH4Desti = Net quantity of CH4 treated or destroyed by treatment or destruction device i during the project reporting period, calculated using equation 5, 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;
Equation 5
CH4Desti = Qi × DEi
Where:
CH4Desti = Net quantity of CH4 treated or destroyed by treatment or destruction device i during the project reporting period, in cubic metres of CH4 at standard conditions;
Qi = Total quantity de CH4 sent to treatment or destruction device i during the project reporting period, calculated using equation 6, in cubic metres of CH4 at standard conditions;
DEi = Default CH4 treatment or destruction efficiency of destruction device i, determined in accordance with Part II;
I = Treatment or destruction device;
Equation 6
Where:
Qi = Total quantity de CH4 sent to treatment or destruction device i during the project reporting period, in cubic metres of CH4 at standard conditions;
n = Number of time intervals during the project reporting period;
t = Time interval shown in the table in Figure 7.1 for which LFG CH4 flow and content measurements are aggregated;
LFGi,t = Corrected volume of LFG sent to treatment or destruction device i, in time interval t, in cubic metres at standard conditions;
PRCH4,t = Average CH4 fraction of the LFG in time interval t, in cubic metres of CH4 per cubic metre of LFG.
(6.2) Calculation method for GHG project emissions
The promoter must calculate the GHG project emissions using equations 7 to 10:
Equation 7
PE = FFCO2 + ELCO2 + NGemissions
Where:
PE = Project emissions during the project reporting period, in metric tonnes CO2 equivalent;
FFCO2 = Total CO2 emissions attributable to the use of fossil fuels during the project reporting period, calculated using equation 8, in metric tonnes CO2 equivalent;
ELCO2 = Total CO2 emissions attributable to the consumption of electricity during the project reporting period, calculated using equation 9, in metric tonnes CO2 equivalent;
NGemissions = Total quantity of CH4 and CO2 emissions attributable to supplemental natural gas during the project reporting period, calculated using equation 10, in metric tonnes CO2 equivalent;
Equation 8
Where:
FFCO2 = Total CO2 emissions attributable to the use of fossil fuels during the project reporting 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 in the operation of equipment within the SSRs in the baseline scenario, 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 9
ELPR × ELEL
ELCO2 = ___________
1,000
Where:
ELCO2 = Total CO2 emissions attributable to the consumption of electricity during the project reporting period, in metric tonnes CO2 equivalent;
ELPR = Total electricity consumed by the project LFG capture and treatment or destruction system during the project reporting period, in megawatt-hours;
EFEL = CO2 emission factor for the consumption of electricity from Québec, according to the most recent National Inventory Report: Greenhouse Gas Sources and Sinks in Canada, Part 3, published by Environment Canada, in kilograms of CO2 par megawatt-hour;
1,000 = Conversion factor, metric tonnes to kilograms;
Equation 10
Where:
NGemissions = Total CH4 and CO2 emissions attributable to supplemental natural gas during the project reporting period, in metric tonnes CO2 equivalent;
n = Number of treatment or destruction devices;
i = Treatment or destruction device;
NGi = Total quantity of supplemental natural gas sent to treatment or destruction device i during the project reporting period, in cubic metres at standard conditions;
NGCH4 = Average CH4 fraction of the supplemental natural gas, according to the supplier’s specifications, in cubic metres of CH4 at standard conditions per cubic metre of natural gas 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;
DEi = Default CH4 treatment or destruction efficiency of destruction device i, determined in accordance with Part II;
21 = Global Warming Potential factor of CH4;
12/16 = Molecular mass ratio, carbon to CH4;
44/12 = Molecular mass ratio, CO2 to carbon.
(7) Project surveillance
(7.1) 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.
(7.2) Surveillance plan
The promoter must establish a monitoring plan to measure and monitor project parameters in accordance with 7.1:
Figure 7.1. Project surveillance plan
_________________________________________________________________________________
| | | | | |
|Parameter |Factor |Unit of |Method |Frequency of |
| |used in |measurement | |measurement |
| |equations | | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Capacity and |N/A |Metric tonne |Calculated |Annual or at each|
|annual residual | | | |project reporting|
|material | | | |period, in |
|tonnage | | | |accordance with |
| | | | |the second |
| | | | |paragraph of |
| | | | |section 1 |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Operating status|N/A |Degree Celsius |Measured |Hourly |
|of destruction | |or other, in |for each | |
|devices | |accordance with|destruction | |
| | |this Division |device | |
| | |7.2 | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Corrected |LFGi,t |Cubic metre at |Measured and |Continuous and |
|volume of LFG | |standard |calculated |recorded at least|
|sent to | |conditions | |every 15 minutes |
|destruction | | | |or totalized and |
|device i, in | | | |recorded at least|
|time interval t | | | |daily and |
| | | | |adjusted for |
| | | | |temperature and |
| | | | |pressure |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Uncorrected |LFGuncorrected |Cubic metre |Measured |Only when flow |
|volume of LFG | | | |data are not |
|captured for the| | | |adjusted at |
|given interval | | | |standard |
| | | | |conditions |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Discount factor |DF |0 when the CH4 | |At each project |
|to account for | |content in the | |reporting period |
|uncertainties | |LFG is | | |
|associated with | |continuously | | |
|the monitoring | |monitored, or | | |
|equipment for | |0.1 in other | | |
|CH4 content in | |cases | | |
|the LFG | | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Total quantity |Qi |Cubic metre of |Calculated |Daily when the |
|of CH4 sent to | |CH4 at standard| |CH4 is |
|destruction | |conditions | |continuously |
|device i during | | | |monitored, or |
|the project | | | |weekly if the |
|reporting period| | | |CH4 is monitored |
| | | | |weekly |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Time interval |t |Week, day, |Projects with |Continuous, daily|
|for which LFG | |hour or minute |a continuous |or weekly |
|CH4 flow and | | |CH4 | |
|content | | |concentration | |
|measurements | | |monitoring | |
|are aggregated | | |system may use| |
| | | |the interval | |
| | | |used by their | |
| | | |data | |
| | | |acquisition | |
| | | |system, | |
| | | |provided it is| |
| | | |not more than | |
| | | |1 day for the | |
| | | |continuous | |
| | | |monitoring of | |
| | | |CH4 content | |
| | | |and 1 week for| |
| | | |the weekly | |
| | | |monitoring of | |
| | | |CH4 content | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Average CH4 |PRCH4,t |Cubic metre of |Measured |Continuous or |
|fraction of the | |CH4 at standard|continuously |weekly |
|LFG in time | |conditions per |or by portable| |
|interval t | |cubic metre of |analyzer | |
| | |LFG at standard| | |
| | |conditions | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Total fossil |FFPR,j |Kilogram |Calculated |At each project |
|fuels consumed | |(solid) |using fossil |reporting period |
|by the capture | | |fuel | |
|and destruction | |Cubic metre at |purchasing | |
|system during | |standard |register | |
|the project | |conditions | | |
|reporting | |(gas) | | |
|period, by type | | | | |
|of fuel j | |Litre (liquid) | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Total electricty|ELPR |Megawatt-hour |Measured by |At each project |
|consumed by the | | |onsite meter |reporting period |
|LFG capture and | | |or based on | |
|destruction | | |electricity | |
|system during | | |purchasing | |
|the project | | |register | |
|reporting period| | | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Total quantity |NGi |Cubic metre at |Measured |Continuous |
|of | |standard |before being | |
|supplemental | |conditions |sent to the | |
|natural gas sent| | |destruction | |
|to the | | |device | |
|destruction | | | | |
|device during | | | | |
|the project | | | | |
|reporting | | | | |
|period | | | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|Average CH4 |NGCH4 |Cubic metre of |Based on |At each project |
|fraction of the | |CH4 at standard|purchasing |reporting period |
|supplemental | |conditions per |register | |
|natural gas, | |cubic metre of | | |
|according to the| |natural gas at | | |
|supplier’s | |standard | | |
|specifications | |conditions | | |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|LFG temperature |T |°C |Measured |Continuous |
|________________|_______________|_______________|______________|_________________|
| | | | | |
|LFG pressure |P |kPa |Measured |Continuous |
|________________|_______________|_______________|______________|_________________|
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 7.1;
(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 LFG capture and treatment or destruction system, including the placement of all measurement instrument and equipment that affect included SSRs.
The promoter is responsible for carrying out and monitoring project performance. The promoter must use the LFG treatment or 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 LFG before being delivered to the treatment or destruction device, continuously, recorded every 15 minutes or totalized and recorded at least daily, adjusted for temperature and pressure; and
(2) the CH4 content of the LFG sent to each treatment or destruction device, continuously, recorded every 15 minutes and totalized as an average at least daily. The CH4 content may also be determined by daily to weekly measurements using a calibrated portable analyzer and applying a 10% discount to the total quantity of CH4 captured and eliminated, calculated using equation 4.
Despite the third paragraph, in the case of projects carried out between 1 January 2007 and 31 December 2012, during that period the flow of LFG referred to in subparagraph 1 this paragraph may have been recorded every 60 minutes and the CH4 content of the LFG referred o in subparagraph 2 of this paragraph may have been recorded every 60 minutes.
When temperature and pressure must be measured to correct flow values at standard conditions, the parameters must be measured continuously.
The operating status of the LFG treatment or destruction device must be monitored and recorded at least hourly.
The operating status of flares is established by thermocouple readings above 260 °C.
For all other treatment or destruction devices, the promoter must show in the project plan that a monitoring device has been installed to verify the operation of the treatment or destruction device. The promoter must also show in each 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 treatment or destruction device or the monitoring device for the operation of the treatment or destruction device is not operating.
(7.3) Measurement instruments
The promoter must ensure that all LFG flow meters and CH4 analyzers are
(1) cleaned and inspected as specified in the project’s monitoring plan and at the minimum cleaning and inspection frequency specified by the manufacturer, with all cleaning and inspection activities documented by landfill site personnel;
(2) not more than 2 months before or after the project reporting period end date, either
(a) checked for calibration accuracy by a qualified and independent person, using a portable instrument, such as a pito tube, or 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, according to the manufacturer’s specifications 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 at the landfill site.
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 at the landfill site.
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.
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, all the data from the piece of equipment must be corrected according to the following procedure:
(1) when the calibration indicates an under-reporting of flow rates or CH4 content, the promoter must use the measured values without correction;
(2) when the calibration indicates an over-reporting of flow rates or CH4 content, the promoter must apply to the measured values 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 project reporting period.
If the promoter uses a portable CH4 analyzer, it must be maintained and calibrated according to the manufacturer’s specifications, and calibrated at least annually by the manufacturer, by a laboratory certified by the manufacturer, or by an ISO 17025 accredited laboratory. The portable analyzer also must be calibrated to a known sample gas prior to each use.
No offset credit may be issued for a project reporting period when the calibration or verification of the calibration accuracy of the required instruments has not been correctly carried out and documented.
(7.4) 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 monitoring plan;
(2) information on each flow meter, CH4 analyzer and destruction device used, including type, model number, serial number and manufacturer’s maintenance and calibration procedures;
(3) for a portable analyzer, the date, time and place where measurements are taken and, for each measurement, the CH4 content in the LFG;
(4) 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;
(5) the maintenance records for capture, destruction and monitoring systems;
(6) operating records showing the quantity of residual material disposed of.
(7.5) 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
_________________________________________________________________________________
| | |
| Treatment or 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 |
|________________________________________|________________________________________|
| | |
| Boiler following upgrade and injection | 0.96 |
| into a pipeline | |
|________________________________________|________________________________________|
| | |
| CH4 liquefaction unit | 0.95 |
|________________________________________|________________________________________|
Part III
Missing data – replacement methods
The replacement methods below may be used only
(1) for CH4 content or LFG flow rate parameters;
(2) for missing data on gas flow rates that are discrete, non-chronic and due to unforeseen circumstances;
(3) when the proper functioning of the treatment or destruction device can be shown by thermocouple readings at the flare or other device;
(4) when data on LFG flow rate only, or CH4 content only, are missing;
(5) to replace data on LFG flow rates when a continuous analyzer is used to measure CH4 content and when it is shown that CH4 content was consistent with normal operations for the time when the data are missing; and
(6) to replace data on CH4 content when it is shown that the LFG 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.
_________________________________________________________________________________
| | |
| Missing data period | Replacement method |
|____________________________|____________________________________________________|
| | |
| Less than 6 hours | Use the average of the 4 hours immediately before |
| | and following the missing data period |
|____________________________|____________________________________________________|
| | |
| 6 to less than 24 hours | Use the 90% upper or lower confidence limit of the |
| | 24 hours prior to and after the missing data |
| | period, whichever results in greater |
| | conservativeness |
|____________________________|____________________________________________________|
| | |
| 1 to 7 days | Use the 95% upper or lower confidence limit of the |
| | 72 hours prior to and after the missing data |
| | period, whichever results in greater |
| | conservativeness |
|____________________________|____________________________________________________|
| | |
| More than 7 days | No data may be replaced and no reduction may be |
| | credited |
|____________________________|____________________________________________________|
PROTOCOL 3
DESTRUCTION OF OZONE DEPLETING SUBSTANCES CONTAINED IN INSULATING FOAM OR USED AS REFRIGERANTS REMOVED FROM REFRIGERATION, FREEZER AND AIR-CONDITIONING APPLIANCES
Part I
For the purposes of this protocol,
(1) “container” means an air-tight, waterproof unit used for storing or transporting ODS without leakage or escape of ODS into the environment;
(2) “CFC”: chlorofluorocarbons;
(3) “HCFC”: hydrochlorofluorocarbons;
(3.1) “foam”: insulating foam removed from refrigeration or freezer appliances;
(4) “ODS contained in foam”: ozone depleting substances of the following types:
(a) CFC-11;
(b) CFC-12;
(c) HCFC-22;
(d) HCFC-141b;
(5) “ODS used as refrigerants”: ozone depleting substances of the following types:
(a) CFC-11;
(b) CFC-12;
(c) CFC-13;
(d) CFC-113;
(e) CFC-114;
(f) CFC-115;
(6) “ODS”: ODS contained in foam and ODS used as refrigerants;
(7) “substitute refrigerants”: refrigerants used to replace refrigerants destroyed by a project.
For the purposes of this protocol, chlorofluorocarbons (CFC) and hydrochlorofluorocarbons (HCFC) are greenhouse gases.
(1) Projects covered
(1.1) Eligible ODS
This offset credit protocol covers projects for all activities associated with the destruction of ODS contained in foam or used as refrigerants removed from refrigeration, freezer or air-conditioning appliances recovered in Canada.
Ozone depleting substances contained in foam removed from refrigeration or freezer appliances and ODS used as refrigerants removed from equipment, systems or appliances from industrial, commercial, institutional or residential sources or removed from ODS stored by such sources for their future use or their disposal, and used for refrigeration, freezing and air conditioning are admissible for the purposes of this protocol.
When ODS used as refrigerants targeted by a project are removed from refrigeration, freezer or air-conditioning appliances that also contain ODS contained in foam, the project must also, for any destruction activity taking place after 22 October 2016, provide for the extraction and destruction of the ODS contained in the foam in accordance with this protocol.
(1.2) Duration
A project may cover a maximum period of 5 years provided that, during each year following registration,
(1) the extraction and destruction locations and methods are the same;
(2) the types of appliances from which ODS are extracted are the same; and
(3) the project is continuous over the entire period, in other words at least one destruction occurs each year and a project report is submitted.
In other cases, the ODS must be destroyed within 12 months from the project start date. A new project registration application must be made for any ODS destruction activity occurring after that period.
(2) First project report
In addition to the information required under second paragraph of section 70.5 of this Regulation, the first project report must include the following information:
(1) the name and contact information of the facility removing foam or refrigerants or extracting ODS, of the destruction facility and, where applicable, of the enterprise that carries out such activities;
(2) the name and contact information of any technical consultants;
(3) a list of all the points of origin of each type of ODS destroyed under the project, namely the first place where the appliances with ODS are stored, by Canadian province or territory;
(4) a description of the methods used to remove foam or refrigerants from the appliances, extract ODS from the foam and destroy the ODS;
(5) an estimate of the quantity of foam and ODS recovered, by type of ODS and according to whether the ODS are contained in the foam or are used as refrigerants, in metric tonnes.
(3) Location
The ODS contained in the foam must be destroyed in a facility located in Canada or the United States. However, removal of the foam and refrigerants from the appliances and extraction of the ODS from the foam must be carried out in Canada. Foam, ODS and appliances recovered outside Canada are not eligible for the issue of offset credits under this protocol.
(4) Additionnality
For the purposes of subparagraph b of paragraph 6 of section 70.3 of this Regulation, the project is considered to go beyond current practice if it meets the conditions in Divisions 1 to 3 of this protocol.
(5) Extraction and destruction
ODS must be extracted and destroyed as follows:
(1) ODS contained in foam must be extracted in concentrated form using a negative pressure process;
(2) all ODS must be collected, stored and transported in hermetically sealed containers;
(3) all ODS must be destroyed in concentrated form in an ODS destruction facility meeting the requirements in Division 10 of this protocol
(6) SSRs within the reduction project boundary
Figures 6.1 to 6.3 show 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 6.1. Flowchart for the reduction project process for the ODS contained in the foam
Figure 6.1.1. Chart showing the reduction project process for ODS used as refrigerants
Figure 6.2. Reduction project SSRs targeted in the calculation of GHG emissions under the baseline scenario and project scenario for ODS contained in foam
_________________________________________________________________________________
| | | | | |
|SSR # |Description |Type of |Relevant to |Included|
| | |emission|project | or |
| | | |baseline |Excluded|
| | | |scenario (B)| |
| | | |and/or | |
| | | |Project (P) | |
|__________________|_______________________________|________|____________|________|
| | | | | | |
| 1 |Appliance |Fossil fuel emissions | CO2 | B, P |Excluded|
| |collection |attributable to the collection |________|____________|________|
| | |and transportation of end-of- | | | |
| | |life appliances | CH4 | B, P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N20 | B, P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| 2 |Appliance |Emissions of ODS attributable | ODS | B |Included|
| |shredding |to the shredding of appliances | | | |
| | |for materials recovery | | | |
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| 3 |ODS Extraction|Emissions of ODS attributable | ODS | P |Included|
| | |to the removal of foam from | | | |
| | |appliances | | | |
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |Emissions of ODS attributable | ODS | B |Included|
| | |to the disposal of foam at a | | | |
| | |landfill site | | | |
| | |_______________________________|________|____________|________|
| | | | | | |
| | |Emissions of ODS degradation | HFC, | B |Excluded|
| | |products attributable to foam | HCFC | | |
| 4 |Disposal of |disposed of at a landfill site | | | |
| |foam in |_______________________________|________|____________|________|
| |landfill | | | | |
| | |Fossil fuel emissions | CO2 | B |Excluded|
| | |attributable to the |________|____________|________|
| | |transportation of shredded | | | |
| | |foam and disposal at a landfill| CH4 | B |Excluded|
| | |site |________|____________|________|
| | | | | | |
| | | | N2O | B |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| 5 |Transportation|Emissions of fossil fuels | CO2 | P |Included|
| |to the |fossil attributable to the | | | |
| |destruction |transportation of ODS from the | | | |
| |facility |point of origin to the | | | |
| | |destruction facility | | | |
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |Emissions of ODS attributable | ODS | P |Included|
| | |to incomplete destruction at | | | |
| | |destruction facility | | | |
| | |_______________________________|________|____________|________|
| | | | | | |
| | |Emissions from the oxidation | CO2 | P |Included|
| | |of carbon contained in the | | | |
| 6 |Destruction |destroyed ODS | | | |
| |of ODS |_______________________________|________|____________|________|
| | | | | | |
| | |Fossil fuel emissions | CO2 | P |Included|
| | |attributable to the |________|____________|________|
| | |destruction of ODS in a | | | |
| | |destruction facility | CH4 | P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | P |Excluded|
| | |_______________________________|________|____________|________|
| | | | | | |
| | |Indirect emissions attributable| CO2 | P |Included|
| | |to the use of electricity |________|____________|________|
| | | | | | |
| | | | CH4 | P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | P |Excluded|
|___|______________|_______________________________|________|____________|________|
Figure 6.3. SSRs targeted in the calculation of GHG emissions under the baseline scenario and project scenario for ODS used as refrigerants
_________________________________________________________________________________
| | | | | |
|SSR # |Description |Type of |Relevant to |Included|
| | |emission|project | or |
| | | |baseline |Excluded|
| | | |scenario (B)| |
| | | |and/or | |
| | | |Project (P) | |
|__________________|_______________________________|________|____________|________|
| | | | | | |
| 1 |Appliance |Fossil fuel emissions | CO2 | B, P |Excluded|
| |collection |attributable to the collection |________|____________|________|
| | |and transportation of end-of- | | | |
| | |life appliances | CH4 | B, P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N20 | B, P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |Emissions of ODS attributable | ODS | B, P |Excluded|
| | |to the extraction and | | | |
| | |collection of refrigerants | | | |
| | |from end-of-life equipment or | | | |
| | |equipment undergoing | | | |
| | |maintenance | | | |
| 2 |ODS extraction|_______________________________|________|____________|________|
| | | | | | |
| | |Fossil fuel emissions | CO2 | B, P |Excluded|
| | |attributable to the |________|____________|________|
| | |extraction and collection of | | | |
| | |refrigerants from end-of-life | CH4 | B, P |Excluded|
| | |equipment or equipment |________|____________|________|
| | |undergoing maintenance | | | |
| | | | N2O | B, P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |ODS emissions attributable to | ODS | B, P |Excluded|
| | |equipment leakage and | | | |
| | |maintenance | | | |
| 3 |Industrial |_______________________________|________|____________|________|
| |and | | | | |
| |commercial |Fossil fuel emissions | CO2 | B, P |Excluded|
| |refrigeration |attributable to the operation |________|____________|________|
| | |of refigeration and air - | | | |
| | |conditioning equipment | CH4 | B, P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | B, P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |Substitute refrigerant | CO2e | P |Excluded|
| | |emissions during production | | | |
| 4 |Production of |_______________________________|________|____________|________|
| |substitute | | | | |
| |refrigerant |Fossil fuel emissions | CO2 | P |Excluded|
| | |during the production of |________|____________|________|
| | |substitute refrigerants | | | |
| | | | CH4 | P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| 5 |Transportation|Fossil fuel emissions | CO2 | P |Included|
| |to the |attributable to the |________|____________|________|
| |destruction |transportation of ODS from the | | | |
| |facility |point of origin to the | CH4 | P |Excluded|
| | |destruction facility |________|____________|________|
| | | | | | |
| | | | N2O | P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |Emissions of ODS attributable | ODS | B |Included|
| | |to leakage and maintenance | | | |
| | |during the continuous operation| | | |
| | |of equipment | | | |
| | |_______________________________|________|____________|________|
| | | | | | |
| | |Substitute refrigerant | CO2e | P |Included|
| | |emissions attributable to | | | |
| | |leakage and maintenance during | | | |
| | |the continous operation of | | | |
| | |equipment | | | |
| 6 |Refrigeration |_______________________________|________|____________|________|
| | | | | | |
| | |Indirect emissions | CO2 | B, P |Excluded|
| | |attributable to the use of |________|____________|________|
| | |electricity | | | |
| | | | CH4 | B, P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | B, P |Excluded|
|___|______________|_______________________________|________|____________|________|
| | | | | | |
| | |Emissions of ODS attributable | ODS | P |Included|
| | |to incomplete destruction at | | | |
| | |the destruction facility | | | |
| | |_______________________________|________|____________|________|
| | | | | | |
| | |Emissions from the oxidation | CO2 | P |Included|
| | |of carbon contained in the | | | |
| | |destroyed ODS | | | |
| 7 |Destruction |_______________________________|________|____________|________|
| | | | | | |
| | |Fossil fuel emissions | CO2 | P |Included|
| | |attributable to the destruction|________|____________|________|
| | |of ODS in a destruction | | | |
| | |facility | CH4 | P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | P |Excluded|
| | |_______________________________|________|____________|________|
| | | | | | |
| | |Indirect emissions | CO2 | P |Included|
| | |attributable to the use of |________|____________|________|
| | |electricity | | | |
| | | | CH4 | P |Excluded|
| | | |________|____________|________|
| | | | | | |
| | | | N2O | P |Excluded|
|___|______________|_______________________________|________|____________|________|
(7) Calculation method for total GHG emission reductions attributable to a project
In calculating the GHG emission reductions attributable to a project for the destruction of ODS, the promoter must calculate the reductions attributable to the destruction of ODS contained in foam separately from those attributable to the destruction of ODS used as refrigerants.
The promoter must calculate the total GHG emission reductions using equation 1:
Equation 1
ERT = ERF + ERR
Where:
ERT = Total GHG emission reductions attributable to the project during the project reporting period, in metric tonnes CO2 equivalent;
ERF = Total GHG emission reductions attributable to the destruction of ODS contained in foam during the project reporting period, calculated using equation 2, in metric tonnes CO2 equivalent;
ERR = Total GHG emission reductions attributable to the destruction of ODS used as refrigerants during the project reporting period, calculated using equation 6.2, in metric tonnes CO2 equivalent.
For the purposes of the equations, the promoter must use the global warming potential of ODS shown in Figure 7.1:
Figure 7.1. Global warming potential of ODS
_________________________________________________________________________________
| | |
| Type of ODS | Global warming potential (metric tonnes CO2 |
| | equivalent per metric tonne of ODS) |
|______________________________|__________________________________________________|
| | |
| CFC-11 | 4,750 |
|______________________________|__________________________________________________|
| | |
| CFC-12 | 10,900 |
|______________________________|__________________________________________________|
| | |
| CFC-13 | 14,400 |
|______________________________|__________________________________________________|
| | |
| CFC-113 | 6,130 |
|______________________________|__________________________________________________|
| | |
| CFC-114 | 10,000 |
|______________________________|__________________________________________________|
| | |
| CFC-115 | 7,370 |
|______________________________|__________________________________________________|
| | |
| HCFC-22 | 1,810 |
|______________________________|__________________________________________________|
| | |
| HCFC-141b | 725 |
|______________________________|__________________________________________________|
(7.1) Calculation method for GHG emission reductions under a project for the destruction of ODS contained in foam
The promoter must calculate GHG emission reductions under a project for the destruction of ODS contained in foam using equation 2:
Equation 2
ERF = BEF - PEF
Where:
ERF = Total GHG emission reductions attributable to the project for the destruction of ODS contained in foam during the project reporting period, in metric tonnes CO2 equivalent;
BEF = Baseline emissions attributable to the destruction of ODS contained in foam during the project reporting period, calculated using equation 3, in metric tonnes CO2 equivalent;
PEF = GHG emissions under the project for the destruction of ODS contained in foam during the project reporting period, calculated using equation 5, in metric tonnes CO2 equivalent.
(7.1.1) Calculation of GHG emissions under the baseline scenario under a project for the destruction of ODS contained in foam
The promoter must calculate GHG emissions under the baseline scenario attributable to ODS-containing foam using equations 3 and 4:
Equation 3
Where:
BEF = Baseline emissions attributable to the destruction of ODS contained in foam during the project reporting period, in metric tonnes CO2 equivalent;
i = Type of ODS;
n = Number of types of ODS;
BAinit, i = Initial quantity of ODS of type i contained in foam prior to removal from appliances, calculated using equation 4, in metric tonnes of ODS of type i;
EFF,i = GHG emission factor for ODS of type i contained in foam, as indicated in the table in Figure 7.2;
GWPi = Global warming potential of ODS of type i as indicated in the table in Figure 7.1, in metric tonnes CO2 equivalent per metric tonne of ODS of type i;
Equation 4
Where:
BAinit, i = Initial quantity of ODS of type i contained in foam prior to removal from appliances, in metric tonnes of ODS of type i;
BAfinal, i = Total quantity of ODS of type i extracted and sent for destruction, determined in accordance with Division 9, in metric tonnes of ODS of type i;
EE = Extraction efficiency of the ODS extraction process, calculated in accordance with the method in Part II;
i = Type of ODS.
Figure 7.2. Emission factor for each type of ODS contained in foam removed from appliances
_________________________________________________________________________________
| | |
| Type of ODS | Emission factor for each type of ODS contained |
| | in foam removed from appliances (EFF,i) |
|______________________________|__________________________________________________|
| | |
| CFC-11 | 0.44 |
|______________________________|__________________________________________________|
| | |
| CFC-12 | 0.55 |
|______________________________|__________________________________________________|
| | |
| HCFC-22 | 0.75 |
|______________________________|__________________________________________________|
| | |
| HCFC-141b | 0.50 |
|______________________________|__________________________________________________|
(7.1.2) Calculation of GHG emissions under a project for the destruction of ODS contained in foam
The promoter must calculate GHG emissions under a project for the destruction of ODS contained in foam using equations 5 to 6.1.
Equation 5
PEF = BApr + (Tr + DEST)F
Where:
PEF = GHG emissions under a project for the destruction of ODS contained in foam during the project reporting period, in metric tonnes CO2 equivalent;
BApr = Total quantity of ODS contained in foam that are emitted during extraction, calculated using equation 6, in metric tonnes CO2 equivalent;
(Tr + DEST)F = GHG emissions attributable to the transportation and destruction of ODS contained in foam, calculated using equation 6.1, in metric tonnes CO2 equivalent;
Equation 6
Where:
BApr = Total emissions attributable to the extraction of ODS contained in foam removed from appliances, in metric tonnes CO2 equivalent;
i = Type of ODS;
n = Number of types of ODS;
BAinit,i = Total quantity of ODS of type i contained in foam removed from appliances prior to extraction, calculated using equation 4, in metric tonnes of ODS of type i;
EEF = Extraction efficiency of the extraction process for ODS contained in foam, determined for the project using the method in Part II;
GWPi = Global warming potential of ODS of type i as indicated in the table in Figure 7.1, in metric tonnes CO2 equivalent per metric tonne of ODS of type i;
Equation 6.1
(Tr + DEST)F = BAfinal × 7.5
Where:
(Tr + DEST)F = GHG emissions attributable to the transportation and destruction of ODS contained in foam, in metric tonnes CO2 equivalent;
BAfinal = Total quantity of ODS contained in foam sent for destruction under the project, calculated using equation 10, in metric tonnes of ODS;
7.5 = Default emission factor for ODS transportation and destruction, in metric tonnes CO2 equivalent per metric tonne of ODS.
(7.2) Calculation method for total GHG emission reductions under a project for the destruction of ODS used as refrigerants
The promoter must calculate GHG emission reductions under a project for the destruction of ODS used as refrigerants using equation 6.2:
Equation 6.2
ERR = BER - PER
Where:
ERR = Total GHG emission reductions attributable to the project for the destruction of ODS used as refrigerants during the project reporting period, in metric tonnes CO2 equivalent;
BER = Baseline emissions attributable to the destruction of ODS used as refrigerants during the project reporting period, calculated using equation 6.3, in metric tonnes CO2 equivalent;
PER =GHG emissions under the project for the destruction of ODS used as refrigerants during the project reporting period, calculated using equation 6.4, in metric tonnes CO2 equivalent.
(7.2.1) Calculation of GHG emissions under the baseline scenario under a project for the destruction of ODS used as refrigerants
The promoter must calculate GHG emissions under the baseline scenario under a project for the destruction of ODS used as refrigerants using equation 6.3:
Equation 6.3
Where:
BER = Emissions under the baseline scenario attributable to the destruction of ODS used as refrigerants during the project reporting period, in metric tonnes CO2 equivalent;
i = Type of ODS;
n = Number of types of ODS;
Qi = Total quantity of ODS of type i used as refrigerants recovered and sent for destruction, determined in accordance with Division 9, in metric tonnes of ODS of type i;
EFR,i = GHG emission factor for ODS of type i used as refrigerants, as indicated in the table in Figure 7.3;
GWPi = Global warming potential of ODS of type i as indicated in the table in Figure 7.1, in metric tonnes CO2 equivalent per metric tonne of ODS of type i;
Figure 7.3. Emission factor for each type of ODS used as a refrigerant
_________________________________________________________________________________
| | |
| Type of ODS | Emission factor for each type of ODS used as a |
| | refrigerant (EFR,i) |
|______________________________|__________________________________________________|
| | |
| CFC-11 | 0.89 |
|______________________________|__________________________________________________|
| | |
| CFC-12 | 0.95 |
|______________________________|__________________________________________________|
| | |
| CFC-13 | 0.61 |
|______________________________|__________________________________________________|
| | |
| CFC-113 | 0.89 |
|______________________________|__________________________________________________|
| | |
| CFC-114 | 0.78 |
|______________________________|__________________________________________________|
| | |
| CFC-115 | 0.61 |
|______________________________|__________________________________________________|
(7.2.2) Calculation of GHG emissions under a project for the destruction of ODS used as refrigerants
The promoter must calculate total GHG emissions under a project for the destruction of ODS used as refrigerants using equations 6.4 to 6.7:
Equation 6.4
PER = Sub + (Tr + Dest)R
Where:
PER = GHG emissions under the project for the destruction of ODS used as refrigerants during the project reporting period, in metric tonnes CO2 equivalent;
Sub = Total GHG emissions attributable to substitute refrigerants, calculated using equation 6.5, in metric tonnes CO2 equivalent;
(Tr + DEST)R = GHG emissions attributable to the transportation and destruction of ODS used as refrigerants, calculated using equation 6.6, in metric tonnes CO2 equivalent;
Equation 6.5
Where:
Sub = Total GHG emissions attributable to substitute refrigerants, in metric tonnes CO2 equivalent;
i = Type of ODS;
n = Number of types of ODS;
Qi = Total quantity of ODS of type i used as refrigerants recovered and sent for destruction, determined in accordance with Division 9, in metric tonnes of ODS of type i;
EFSi = Emission factor for substitutes for ODS of type i as indicated in the table in Figure 7.4, in metric tonnes CO2 equivalent per metric tonne of ODS;
Figure 7.4. Emission factors for substitute refrigerants
_________________________________________________________________________________
| | |
| ODS used as refrigerants | Emission factors for substitute |
| | refrigerants (EFSi) |
|______________________________|__________________________________________________|
| | |
| CFC-11 | 223 |
|______________________________|__________________________________________________|
| | |
| CFC-12 | 686 |
|______________________________|__________________________________________________|
| | |
| CFC-13 | 7,144 |
|______________________________|__________________________________________________|
| | |
| CFC-113 | 220 |
|______________________________|__________________________________________________|
| | |
| CFC-114 | 659 |
|______________________________|__________________________________________________|
| | |
| CFC-115 | 1,139 |
|______________________________|__________________________________________________|
Equation 6.6
(TR + Dest)R = Q × 7.5
Where:
(Tr + DEST)R = GHG emissions attributable to the transportation and destruction of ODS used as refrigerants, in metric tonnes CO2 equivalent;
Q = Total quantity of ODS used as refrigerants recovered and sent for destruction, calculated using equation 6.7, in metric tonnes of ODS;
7.5 = Default emission factor for ODS transportation and destruction, in metric tonnes CO2 equivalent per metric tonne of ODS;
Equation 6.7
Where:
Q = Total quantity of ODS used as refrigerants recovered and sent for destruction, in metric tonnes of ODS;
i = Type of ODS;
n = Number of types of ODS;
Qi = Total quantity of ODS of type i used as refrigerants recovered and sent for destruction, determined in accordance with Division 9, in metric tonnes of ODS of type i.
(8) Data management and project surveillance
(8.1) Data management
The promoter must record the following information in the register referred to in section 70.13, and include it in the project report referred to in the second paragraph of section 70.14, indicating separately the information pertaining to ODS contained in foam and that pertaining to ODS used as refrigerants:
(1) information on the chain of traceability, from point of origin to point of destruction of the ODS;
(2) information on the point of origin, namely the first place of storage for recovered appliances with ODS-containing foam, specifying
(a) the address of each place of storage where recovered appliances are transferred or aggregated;
(b) the name and contact information of each party involved in each stage of the project, and the quantity of materials, whether appliances, foam or ODS, transferred, sold or handled by each party; and
(c) the number of appliances recovered and, for each appliance, the type, size, storage capacity and, if available, serial number;
(3) the serial number or identification number of the containers used for ODS storage and transportation;
(4) any document identifying persons in possession of appliances, foam and ODS at each stage in the project, and showing the transfer of possession and ownership of the appliances, foam and ODS;
(5) information on ODS extraction, specifying
(a) the number of appliances containing foam from which ODS has been extracted;
(a.1) the number of appliances containing refrigerants from which ODS have been extracted;
(b) the name and contact information of the facility where the ODS are extracted;
(c) the name and contact information of the facility where the appliances are recycled, if any; and
(d) processes, training, and quality assurance, quality control and extraction process management processes;
(6) a certificate of destruction for all the ODS destroyed under the project, issued by the facility that destroyed the ODS, by destruction activity, specifying
(a) the name of the project promoter;
(b) the name and contact information of the destruction facilities;
(c) the name and signature of the person responsible for the destruction operations;
(d) the identification number on the certificate of destruction;
(e) the serial, tracking or identification number of all containers for which ODS destruction occurred;
(f) the weight and type of ODS destroyed for each container, including the weigh tickets generated in accordance with Division 9.1;
(g) the destruction start date and time; and
(h) the destruction end date and time;
(7) the surveillance plan referred to in Division 8.2;
(8) the certificate of sampling results issued by the laboratory in accordance with Division 9.1.
All the data referred to in subparagraph 2 of the first paragraph concerning the point of origin must be obtained at the time of recovery from the point of origin.
(8.2) Surveillance plan
The promoter must establish a surveillance plan to measure and monitor project parameters in accordance with the tables in figures 8.1 and 8.2
Figure 8.1. Parameters for the surveillance of a project for the destruction of ODS contained in foam
_________________________________________________________________________________
| | | | | |
| Parameter | Factor | Measurement | Method | Measurement |
| | used in | unit | | frequency |
| | equations | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of ODS | BAinit | Metric tonne| Calculated | Each project|
| contained in foam prior | | of ODS | | reporting |
| to removal from | | | | period |
| appliances | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Initial quantity of ODS | BAinit, i | Metric tonne| Calculated | Each project|
| of type i contained in | | of ODS of | | reporting |
| foam from appliances | | type i | | period |
| prior to removal | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Recovery efficiency | RE | O ≤ 1 | Calculated | Each project|
| associated with the | | | | reporting |
| process for the | | | | period |
| extraction of ODS | | | | |
| contained in foam | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of foam | Foamrec | Metric tonne| Measured and| Each project|
| removed prior to | | of foam | calculated | reporting |
| extraction of ODS | | | | period |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total emissions | BApr | Metric | Calculated | Each project|
| attributable to the | | tonne, CO2 | | reporting |
| extraction of ODS from | | equivalent | | period |
| foam removed from | | | | |
| appliances | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of ODS | BAfinal | Metric tonne| Calculated | Each project|
| contained in the foam | | of ODS | | reporting |
| removed and sent for | | | | period |
| destruction | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of ODS | BAfinal, i | Metric tonne| Calculated | Each project|
| of type i contained in | | of ODS of | | reporting |
| foam extracted and sent | | type i | | period |
| for destruction | | | | |
| under the project | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Mass of each container | N/A | Metric tonne| Measured | Each project|
| filled with ODS | | | | reporting |
| contained in foam | | | | period |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Mass of each empty | N/A | Metric tonne| Calculated | Each project|
| container for projects | | | | reporting |
| to destroy ODS contained| | | | period |
| in foam | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Quantity of ODS | N/A | Metric tonne| Calculated | Each project|
| contained in foam, in | | | | reporting |
| container each | | | | period |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Concentration of each | N/A | % | Measured | Each project|
| type of ODS contained | | | | reporting |
| in foam, in each | | | | period |
| container | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Quantity of each type | N/A | Metric | Calculated | Each project|
| of ODS contained in | | tonnes of | | reporting |
| foam, in each container | | ODS of | | period |
| | | type i | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Emissions attributable | (TR + DEST) | Metric | Calculated | Each project|
| to the transportation | | tonne, CO2 | | reporting |
| and destruction of ODS | | equivalent | | period |
| contained in foam | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Concentration of ODS | CBA | Metric tonne| Calculated | Each project|
| in foam before | | of ODS per | | reporting |
| extraction from | | metric tonne| | period |
| appliances | | of foam | | |
|_________________________|_____________|_____________|_____________|_____________|
Figure 8.2. Parameters for the surveillance of a project for the destruction of ODS used as refrigerants
_________________________________________________________________________________
| | | | | |
| Parameter | Factor used | Measurement | Method | Measurement |
| | in equations| unit | | frequency |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Mass of each container | N/A | Metric | Measured | Each project|
| filled with ODS used as | | tonne | | reporting |
| refrigerants | | | | period |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Mass of each empty | N/A | Metric | Measured | Each project|
| container for project | | tonne | | reporting |
| to destroy ODS used as | | | | period |
| refrigerants | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Quantity of ODS used | N/A | Metric | Calculated | Each project|
| as refrigerants, in | | tonne | | reporting |
| each container | | | | period |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Concentration of each | N/A | % | Analysed in | Each project|
| type of ODS used as a | | | a laboratory| reporting |
| refrigerant, in each | | | | period |
| container | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Quantity of each type | N/A | Metric | Calculated | Each project|
| of ODS used as a | | tonne of | | reporting |
| refrigerant, in each | | ODS of | | period |
| container | | type i | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of ODS | Qi | Metric | Calculated | Each project|
| of type i used as | | tonne of | | reporting |
| refrigerants removed and| | ODS of | | period |
| sent for destruction | | type i | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of ODS | Q | Metric | Calculated | Each project|
| used as refrigerants | | tonne of | | reporting |
| removed and sent for | | ODS | | period |
| destruction | | | | |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Total quantity of GHG | Sub | Metric | Calculated | Each project|
| emissions from | | tonne CO2 | | reporting |
| substitute refrigerants | | equivalent | | period |
|_________________________|_____________|_____________|_____________|_____________|
| | | | | |
| Emissions attributable | (Tr + DEST)R| Metric | Calculated | Each project|
| to the transportation | | tonne CO2 | | reporting |
| and destruction of ODS | | equivalent | | period |
| used as refrigerants | | | | |
|_________________________|_____________|_____________|_____________|_____________|
(9) Extraction and analysis of ODS extracted in concentrated form from foam removed from appliances and of ODS used as refrigerants
In the case of ODS contained in foam, the promoter must use the same procedure during project implementation as that used to calculate extraction efficiency using the method in Part II of this protocol.
For each container, the promoter must use the method in this Division to calculate, on a mass basis, the total quantity of ODS of type i sent for destruction under the project, namely the factor BAfinal,i for projects for the destruction of ODS contained in foam and the factor Qi for projects for the destruction of ODS used as refrigerants.
(9.1) Determination of the quantity of ODS in each container
The quantity of ODS destroyed must be determined at the destruction facility by an authorized person, by weighing each container when it is full of ODS prior to destruction and after it has been emptied and its contents have been destroyed.
The quantity of ODS is equal to the difference between the mass of the container when full and when empty.
Each ODS container must be weighed at the destruction facility:
(1) using a single scale to generate both full and empty weight tickets;
(2) ensuring that the scale has been calibrated by the manufacturer or by a third person certified for that purpose less than 3 months before the weighing, to an accuracy of ± 5%;
(3) weighing the full container not more than 2 days prior to commencing the destruction of the ODS;
(4) weighing the empty container not more than 2 days after the destruction of the ODS.
Despite the first paragraph, until 31 December 2014, the containers may be weighed in a place other than the destruction facility provided it is less than 5 km from the facility.
Despite subparagraph 2 of the third paragraph, scales used prior to 31 December 2012 and subject to the Weights and Measures Act (R.S.C. 1985, c. W-6) may have been calibrated at the frequency specified by Measurement Canada provided that frequency does not exceed 2 years. However, if the first calibration after a weighing indicates that the weight of the ODS destroyed was overestimated, the promoter must correct the weight by deducting the error percentage recorded during the calibration.
(9.2) Circulation of mixed ODS
For each sample that does not contain over 90% of the same type of ODS, the promoter must, in addition to the conditions provided for in Division 9.1, also meet the following conditions concerning mixed ODS.
The circulation of the ODS mixture must be conducted at the destruction facility or prior to delivery of the ODS to such a facility, by a person who is independent of the promoter and of the destruction facility and who is properly trained to carry out this task.
The promoter must include the procedures used to analyze the ODS mixture in the project report.
Prior to sampling, the ODS mixture must be circulated in a container that meets all of the following conditions:
(1) the container has no solid interior obstructions other than mesh baffles or other interior structures that do not impede circulation;
(2) the container was fully evacuated prior to filling;
(3) the container has ports to sample liquid and gas phase ODS;
(4) the sampling ports are located in the middle third of the container and not at one end or the other;
(5) the container and associated equipment can circulate the mixture through a closed loop system from the bottom to top.
If the original mixed ODS container does not meet these requirements, the mixed ODS must be transferred into a compliant temporary container.
The mass of the ODS mixture transferred into the temporary container must be calculated and recorded. In addition, transfers of ODS between containers must be carried out at a pressure that meets the applicable standards for the place where the project is located.
Once the mixed ODS are in a container that meets the above criteria, they must be circulated as follows:
(1) liquid mixtures must be circulated from the liquid port to the vapour port;
(2) a volume of the mixture equal to 2 times the volume in the container must be circulated;
(3) circulation must occur at a rate of at least 114 litres per minute unless the liquid mixture has been circulating continuously for at least 8 hours;
(4) the start and end times must be recorded.
(9.3) Sampling
Sampling must be conducted for each ODS container:
(1) in the case of pure ODS, 1 sample must be taken at the destruction facility;
(2) in the case of ODS mixtures that have been circulated at the destruction facility, a minimum of 2 samples must be taken during the last 30 minutes of circulation and the samples must be taken from the bottom liquid port;
(3) in the case of ODS mixtures that have been circulated prior to delivery to the destruction facility, a minimum of 2 samples must be taken in accordance with subparagraph 2, and 1 additional sample must be taken at the destruction facility.
If more than one sample is taken for a single container, the promoter must use the results from the sample with the weighted ODS concentration with the least global warming potential.
The sampling must be conducted in accordance with the following conditions:
(1) the samples must be taken by a person who is independent of the promoter and of the destruction facility and has the necessary training to carry out this task;
(2) the samples must be taken with a clean, fully evacuated sample bottle with a minimum capacity of 0.454 kg;
(3) each sample must be taken in a liquid state;
(4) a minimum sample size of 0.454 kg must be drawn for each sample;
(5) each sample must be individually labeled and tracked according to the container from which it was taken;
(6) the following information must be recorded for each sample:
(a) the time and date of the sample;
(b) the name of the promoter for whom the sampling is conducted;
(c) the name and contact information of the technician who took the sample, and of the technician’s employer;
(d) the volume of the container from which the sample was drawn;
(e) the ambient air temperature at the time of sampling;
(f) the chain of traceability of each sample, from the point of sampling to the accredited laboratory.
Despite subparagraph 3 of the first paragraph, in the case of ODS mixtures circulated before 31 December 2012, a minimum of 1 sample must be taken in accordance with subparagraph 2 of the first paragraph and 1 extra sample must be taken at the destruction facility.
(9.4) Analysis of samples
The quantity and type of ODS must be determined by having a sample from each container analyzed by one of the following laboratories:
(1) the Centre d’expertise en analyse environnementale du Québec of the department;
(2) a laboratory that is independent of the promoter and of the destruction facility and accredited for analysis of ODS by the Air-Conditioning, Heating and Refrigeration Institute in accordance with the most recent version of AHRI 700 of that organization.
All the ODS samples for the project must be sampled to determine the following:
(1) the type of each ODS;
(2) the quantity, in metric tonnes, and concentration, in metric tonnes of ODS of type i per metric tonne of gas, in each type of ODS in the gas, using gas chromatography;
(3) the moisture content of each sample;
(4) the high boiling residue from the ODS sample, which must be below 10% of the total mass of the sample.
If the moisture content determined under subparagraph 3 of the second paragraph is above 75% of the saturation point for the ODS, the promoter must dry the ODS mixture, take the sample again and analyze it in accordance with the method in Division 9.2 or deduct the weight of the water, which includes the weight of the layer of free water floating on the ODS and the amount of dissolved water in the ODS.
In the case of ODS mixtures, the analysis must determine the weighted concentrations of the ODS on the basis of their global warming potential for samples taken in accordance with subparagraph 2 of the first paragraph of Division 9.3.
A certificate of the sampling results must be issued by the laboratory that conducted the analysis and a copy of the certificate must be included with the project report.
(9.5) Determination of the total quantity of ODS of type i contained in foam extracted and sent for destruction (BAfinal, i) and the total quantity of ODS of type i used as refrigerants extracted and sent for destruction (Qi)
Based on the mass of the ODS in each container and the concentration of each sample, the promoter must
(1) calculate the quantity of each type of ODS in each container, by deducting the weight of the water if the moisture content is above 75% of the saturation point and the ODS has not been dried, and deducting the weight of the high boiling residue;
(2) add together the quantities of each type of ODS in each container to obtain the factor BAfinal, i, namely the total quantity of ODS of type i contained in the foam, or the factor Qi, namely the total quantity of ODS of type i used as refrigerants extracted and sent for destruction under the project.
(10) Destruction facilities
The operating parameters for the facility during ODS destruction must be monitored and recorded in accordance with the Code of Good Housekeeping approved by the Montréal Protocol.
The verifier must use the data to show that, during the ODS destruction process, the facility was operating in conditions that met the requirements of any authorization necessary to pursue activities at that facility.
The promoter must continuously monitor the following parameters during the entire ODS destruction process:
(1) the ODS feed rate;
(2) the operating temperature and pressure of the destruction facility during ODS destruction;
(3) effluent discharges measured in terms of water and pH levels;
(4) carbon monoxide emissions.
Each stage in a project carried out in the United States must be conducted in accordance with the requirements of the most recent version of the protocol entitled “Compliance Offset Protocol Ozone Depleting Substances Projects: Destruction of U.S. Ozone Depleting Substances Banks” and published by the California Air Resources Board and the California Environmental Protection Agency.
(11) Verification
The verification process must include a visit
(1) of the place where ODS contained in foam are extracted, at least once during the first project verification; and
(2) of each destruction facility for the project, during each project verification.
Part II
Calculation of ODS extraction efficiency in foam removed from appliances
To calculate extraction efficiency in accordance with Division 2, the promoter must first calculate the quantity of ODS contained in foam prior to removal from appliances, based on the storage capacity of the appliances, using equation 7 and the table in Figure 1 of Subdivision 1.1 or using foam samples in accordance with Subdivision 1.2.
(1) Calculation methods for the initial quantity of ODS contained in foam
(1.1) Calculation of the initial quantity of ODS contained in foam based on the storage capacity of the appliances
The promoter may calculate the initial quantity of ODS contained in foam using equation 7 and data from the table in Figure 1:
Equation 7
BAinit = (N1 × M1) + (N2 × M2) + (N3 × M3) + (N4 × M4)
Where:
BAinit = Initial quantity of ODS contained in foam prior to removal from appliances, in metric tonnes;
N1 = Number of appliances of type 1;
N2 = Number of appliances of type 2;
N3 = Number of appliances of type 3;
N4 = Number of appliances of type 4;
M1 = Metric tonnes of ODS per appliance of type 1;
M2 = Metric tonnes of ODS per appliance of type 2;
M3 = Metric tonnes of ODS per appliance of type 3;
M4 = Metric tonnes of ODS per appliance of type 4.
Figure 1. Quantity of ODS by type of appliance
_______________________________________________________________________________
| | | |
| Type of appliance | Storage capacity (SC) | Metric tonnes of ODS |
| | | per appliance |
|_____________________|______________________________|__________________________|
| | | |
| Type 1 | SC < 180 litres | 0.00024 |
|_____________________|______________________________|__________________________|
| | | |
| Type 2 | 180 litres ≤ SC < 350 litres | 0.00032 |
|_____________________|______________________________|__________________________|
| | | |
| Type 3 | 350 litres ≤ SC < 500 litres | 0.0004 |
|_____________________|______________________________|__________________________|
| | | |
| Type 4 | SC ≥ 500 litres | 0.00048 |
|_____________________|______________________________|__________________________|
(1.2) Calculation of the initial quantity of ODS contained in foam based on samples
The initial quantity of ODS contained in foam may be calculated using samples from at least 10 appliances and the following method:
(1) have the initial concentration of ODS in the foam determined by a laboratory independent of the promoter in accordance with Division 9.1 of Part I and in the following manner:
(a) by cutting 4 foam samples from each appliance (left side, right side, top, bottom) using a reciprocating saw, each sample being at least 10 cm2 and the full thickness of the insulation;
(b) by sealing the cut edges of each foam sample using aluminum tape or a similar product that prevents off gassing;
(c) by individually labelling each sample to record appliance model and site of sample (left, right, top, bottom);
(d) by analyzing the samples using the procedure in paragraph 4; the samples may be analyzed individually (4 analyses per appliance) or a single analysis may be done using equal masses of foam from each sample (1 analysis per appliance);
(e) based on the average concentration of ODS in the samples from each appliance, by calculating the 90% upper confidence limit of the ODS concentration in the foam, and using that value as the “CBA” factor in equation 8 to calculate initial quantity of ODS contained in foam from appliances;
(2) determine the quantity of foam removed from the appliances processed, namely the factor “Foamrec” in equation 8, using a default value of 5.85 kg per appliance and multiplying by the number of appliances processed or using the following method:
(a) by separating and collecting all foam residual, which may be in a fluff, power or pelletized form, and documenting the processed to demonstrate that no significant quantity of foam residual is lost in the air or other waste streams;
(b) by separating non-foam components in the residual (such as metal or plastic);
(c) by weighing the recovered foam residual prior to ODS extraction to calculate the total mass of foam recovered;
(3) calculate the initial quantity of ODS contained in foam prior to removal from appliances using equation 8:
Equation 8
BAinit = Foamrec × CBA
Where:
BAinit = Initial quantity of ODS contained in foam prior to removal from appliances, in metric tonnes;
Foamrec = Total quantity of foam recovered prior to ODS extraction, in metric tonnes;
CBA = Concentration of ODS in the foam prior to removal from appliances, in metric tonnes de ODS per metric tonne of foam;
(4) analyze the foam samples from appliance in accordance with the following requirements:
(a) the analysis of the content and mass ratio of the ODS from foam must be done at an independent laboratory in accordance with Division 9.1 of Part I;
(b) the analysis must be done using the heating method to extract ODS from the foam in the foam samples, as described in the article “Release of fluorocarbons from Insulation foam in Home Appliance during Shredding” published by Scheutz, Fredenslund, Kjeldsen and Tant in the Journal of the Air & Waste Management Association (December 2007, Vol. 57, pages 1452-1460), and set out below:
i. each sample must be prepared to a thickness no greater than 1 cm, placed in a 1123 ml glass bottle, weighed using a calibrated scale, and sealed with Teflon-coated septa and aluminum caps;
ii. to release the ODS, the sample must be incubated in an oven for 48 hours at 140 °C;
iii. when cooled to room temperature, gas samples must be redrawn from the headspace and analyzed by gas chromatography in accordance with Division 9.1 of Part I;
iv. the lids must be removed after analysis, and the headspace must be flushed with atmospheric air for approximately 5 minutes using a compressor; afterwards, the septa and caps must be replaced and the bottles subjected to a second 48-hour heating step to drive out the remaining ODS from the sampled foam;
v. when cooled down to room temperature after the second heating step, gas samples must be redrawn from the headspace and analyzed by gas chromatography in accordance with Division 9.1 of Part I;
(c) the quantity of each type of ODS recovered must then de divided by the total mass of the initial foam samples prior to analysis to determine the mass ratio of ODS present, in metric tonnes of ODS per metric tonne of foam.
(2) Calculation methods for extraction efficiency
The promoter must calculate the extraction efficiency using equation 9:
Equation 9
BAfinal
EE = _________
BAinit
Where:
EE = Extraction efficiency;
BAfinal = Total quantity of ODS contained in foam removed and sent for destruction, calculated using equation 10, in metric tonnes;
BAinit = Initial quantity of ODS contained in foam prior to removal from appliances, calculated using equation 7 or 8, as the case may be, in metric tonnes;
Equation 10
Where:
BAfinal = Total quantity of ODS contained in foam removed and sent for destruction, in metric tonnes;
i = Type of ODS;
n = Number of types of ODS;
BAfinal, i = Total quantity of ODS of type i extracted and sent for destruction, determined in accordance with Division 9.1 of Part I, in metric tonnes.
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 second 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 project reporting period, in metric tonnes CO2 equivalent;
BE = Emissions under the baseline scenario during the project reporting period, calculated using equation 3, in metric tonnes CO2 equivalent;
PE = Project emissions during the project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting period, in cubic metres of CH4 at standard conditions;
n = Number of time intervals during the project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting period, calculated using equation 6, in metric tonnes CO2 equivalent;
DMCO2 = Total CO2 attributable to the destruction of CH4 during the project reporting period, calculated using equation 7, in metric tonnes CO2 equivalent;
UMCH4 = CH4 emissions attributable to uncombusted CH4 during a project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting 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 project reporting 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
__________________________________________________________________________________
| | | | | |
| Parameter | Factor used | Unit of | Method | Frequency of |
| | in equations| measurement| | measurement |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Operating | N/A | Degree | Measured for | Hourly |
| status of | | Celsius or | each | |
| destruction | | other, | destruction | |
| device | | depending | device | |
| | | on the | | |
| | | device | | |
| | | installed | | |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Uncorrected |MGuncorrected |Cubic metre | Measured | Only when |
| volume of | | | | flow data are |
| mine gas sent | | | | not adjusted |
| to destruction | | | | at standard |
| device i, in | | | | conditions |
| time interval t | | | | |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Volume of | MGi, t | Cubic metre| Measured and | Continuous |
| mine gas sent | | at | calculated | and recorded |
| to destruction | | standard | | at least every |
| device i, in | | conditions | | 15 minutes to |
| time interval t | | | | calculate a |
| | | | | daily average, |
| | | | | and adjusted |
| | | | | for |
| | | | | temperature |
| | | | | and pressure |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Average CH4 | CCH4, t |Cubic metre | Measured | Continuous |
| content in the | | of CH4 per | continuously | and recorded |
| mine gas sent | | cubic metre| | at least every |
| to destruction | | of gas at | | 15 minutes to |
| device during | | standard | | calculate a |
| time interval t | | conditions | | daily average |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Total quantity | FFPR, j | Kilogram | Calculated | At each |
| of fossil fuels | | (solid) | using fossil | reporting |
| combustibles | | | fuel | period |
| consumed by | | Cubic metre| purchasing | |
| the capture | | at standard| register | |
| and | | conditions | | |
| destruction | | (gas) | | |
| system during | | | | |
| the project | | | | |
| reporting | | | | |
| period, by | | Litre | | |
| type of fuel j | | (liquid) | | |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Measured | T | °C | Measured | Hourly |
| temperature | | | | |
| of mine gas | | | | |
|___________________|_____________|____________|________________|__________________|
| | | | | |
| Pressure of | P | kPa | Measured | Hourly |
| mine gas | | | | |
| | | | | |
|___________________|_____________|____________|________________|__________________|
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 project reporting 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 project reporting period.
No offset credit may be issued for a project reporting 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.
__________________________________________________________________________________
| | |
| Missing data period | Replacement method |
|______________________________________|___________________________________________|
| | |
| Less than 6 hours | Use the average of the 4 hours |
| | immediately before and following the |
| | missing data period |
|______________________________________|___________________________________________|
| | |
| 6 to less than 24 hours | Use the 90% upper or lower |
| | confidence limit of the 24 hours prior to |
| | and after the missing data period, |
| | whichever results in greater |
| | conservativeness |
|______________________________________|___________________________________________|
| | |
| 1 to 7 days | Use the 95% upper or lower |
| | confidence limit of the 72 hours prior to |
| | and after the missing data period, |
| | whichever results in greater |
| | conservativeness |
|______________________________________|___________________________________________|
| | |
| More than 7 days | No data may be replaced and no |
| | reduction may be credited |
| | |
|______________________________________|___________________________________________|
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 second 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
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 | Emissions of | CH4 | B, P | Included |
| | ventilation air CH4 | | | |
|_____|_______________________________|_________|______________________|__________|
| | | | | |
| 2 | Emissions | CO2 | B, P | Excluded |
| | attributable to |_________| |__________|
| | energy | | | |
| | consumed to | CH4 | | Excluded |
| | operate mine |_________| |__________|
| | ventilation system | | | |
| | | N2O | | Excluded |
|_____|_______________________________|_________|______________________|__________|
| | | | | |
| 3 | Emissions | CO2 | P | Included |
| | attributable to |_________| |__________|
| | energy | | | |
| | consumed to operate | CH4 | | Excluded |
| | equipment to |_________| |__________|
| | capture and destroy | | | |
| | ventilation air CH4 | N2O | | Excluded |
| | | | | |
|_____|_______________________________|_________|______________________|__________|
| | | | | |
| 4 | Emissions | CO2 | P | Included |
| | from the |_________| |__________|
| | destruction of | | | |
| | ventilation air CH4 | N2O | | Excluded |
| |_______________________________|_________|______________________|__________|
| | | | | |
| | Emissions of | CH4 | P | Included |
| | uncombusted | | | |
| | ventilation air CH4 | | | |
|_____|_______________________________|_________|______________________|__________|
| | | | | |
| 5 | Emissions | CO2 | P | Excluded |
| | from the construction |_________| |__________|
| | and/or | | | |
| | installation of | CH4 | | Excluded |
| | new equipment |_________| |__________|
| | | | | |
| | | N2O | | Excluded |
|_____|_______________________________|_________|______________________|__________|
(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 project reporting period, in metric tonnes CO2 equivalent;
BE = Emissions under the baseline scenario during the project reporting period, calculated using equation 2, in metric tonnes CO2 equivalent;
PE = Project emissions during the project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
n = Number of time intervals during the project reporting 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 project reporting 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 project reporting period, calculated using equation 4, in metric tonnes CO2 equivalent;
DMCO2 = Total CO2 attributable to the destruction of CH4 during a project reporting period, calculated using equation 6, in metric tonnes CO2 equivalent;
UMCH4 = CH4 emissions attributable to uncombusted CH4 during a project reporting 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 project reporting 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 project reporting period, in cubic metres at standard conditions;
VAE = Volume of ventilation air sent to a destruction device during the project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
VAE = Volume of ventilation air sent to a destruction device during the project reporting period, in cubic metres at standard conditions;
VAS = Volume of ventilation air leaving the destruction device during the project reporting period, in cubic metres at standard conditions;
CCH4 = Average CH4 content in ventilation air before entering destruction device during the project reporting 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 project reporting 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 project reporting period, in metric tonnes CO2 equivalent;
VAS = Volume of ventilation air leaving the destruction device during the project reporting period, in cubic metres at standard conditions;
Tdest-CH4 = Average CH4 content in ventilation air leaving the destruction device during the project reporting 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.
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.
(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
__________________________________________________________________________________
| | | | | |
| Parameter | Factor | Unit of | Method | Frequency of |
| | used in | measurement| | measurement |
| | equations | | | |
| | | | | |
| | | | | |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Operating status | N/A | Degree | Measured for | Hourly |
| of destruction | | Celsius or | each | |
| device | | other, | destruction | |
| | | depending | device | |
| | | on the | | |
| | | device | | |
| | | installed | | |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Volume of | VAE | Cubic metre| Measured | Continuous |
| ventilation air | | at standard| and | and recorded |
| sent to | | conditions | calculated | at least every |
| destruction | | | | 2 minutes to |
| device | | | | calculate an |
| | | | | hourly |
| | | | | average, |
| | | | | adjusted for |
| | | | | temperature |
| | | | | and pressure |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Volume of | CA | Cubic metre| Measured | Continuous |
| cooling air added | | at standard| and | and recorded |
| | | conditions | calculated | at least every |
| | | | | 2 minutes to |
| | | | | calculate an |
| | | | | hourly |
| | | | | average, |
| | | | | adjusted for |
| | | | | temperature |
| | | | | and pressure |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Volume of | VAS | Cubic metre| Measured or | Continuous |
| ventilation air | | at standard| calculated | and recorded |
| leaving the | | conditions | | at least every |
| destruction | | | | 2 minutes to |
| device | | | | calculate an |
| | | | | hourly |
| | | | | average, |
| | | | | adjusted for |
| | | | | temperature |
| | | | | and pressure |
|____________________|____________|____________|________________|__________________|
| | | | | |
| CH4 content in | CCH4 | Cubic metre| Measured | Continuous |
| ventilation air | | of CH4 per | | and recorded |
| sent to | | cubic metre| | at least every |
| destruction | | of gas at | | 2 minutes to |
| device during | | standard | | calculate an |
| each project | | conditions | | hourly average |
| reporting period | | | | |
| | | | | |
|____________________|____________|____________|________________|__________________|
| | | | | |
| CH4 content in | CDest-CH4 | Cubic metre| Measured | Continuous |
| ventilation air | | of CH4 per | | and recorded |
| leaving the | | cubic metre| | at least every |
| destruction | | of gas at | | 2 minutes to |
| device during | | standard | | calculate an |
| each project | | conditions | | hourly average |
| reporting period | | | | |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Total quantity of | FFPR, j | Kilogram | Calculated | At each |
| fossil fuels | | (solid) | using fossil | reporting |
| consumed by | | | fuel | period |
| equipment to | | Cubic metre| purchasing | |
| capture and | | at standard| register | |
| destroy | | conditions | | |
| ventilation air | | (gas) | | |
| CH4 during a | | | | |
| project reporting | | Litre | | |
| period, by type of | | (liquid) | | |
| fuel j | | | | |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Temperature of | T | °C | Measured | Hourly |
| ventilation air | | | | |
|____________________|____________|____________|________________|__________________|
| | | | | |
| Pressure of | P | kPa | Measured | Hourly |
| ventilation air | | | | |
|____________________|____________|____________|________________|__________________|
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;
(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.
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 ventilation 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 project reporting 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.
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 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.
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 project reporting period.
No offset credit may be issued for a project reporting 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.
__________________________________________________________________________________
| | |
| Missing data period | Replacement method |
|______________________________________|___________________________________________|
| | |
| Less than 6 hours | Use the average of the 4 hours |
| | immediately before and following the |
| | missing data period |
|______________________________________|___________________________________________|
| | |
| 6 to less than 24 hours | Use the 90% upper or lower |
| | confidence limit of the 24 hours prior to |
| | and after the missing data period, |
| | whichever results in greater |
| | conservativeness |
|______________________________________|___________________________________________|
| | |
| 1 to 7 days | Use the 95% upper or lower |
| | confidence limit of the 72 hours prior to |
| | and after the missing data period, |
| | whichever results in greater |
| | conservativeness |
|______________________________________|___________________________________________|
| | |
| More than 7 days | No data may be replaced and no |
| | reduction may be credited |
| | |
|______________________________________|___________________________________________|