Draft Federal Offset Protocol: Reducing Manure Methane Emissions

Foreword

Canada's Greenhouse Gas (GHG) Offset Credit System is established under Part 2 of the Greenhouse Gas Pollution Pricing Act to provide an incentive to undertake projects that result in domestic GHG reductions that would not have been generated in the absence of the project, that go beyond legal requirements and that are not subject to carbon pollution pricing mechanisms.

Canada's GHG Offset Credit System consists of:

• The Canadian Greenhouse Gas Offset Credit System Regulations (the Regulations), which establish the system, implement the operational aspects and set the general requirements applicable to all project types;
• Federal offset protocols, included in the Compendium of Federal Offset Protocols (the Compendium), each containing requirements for project implementation and methods for quantifying GHG reductions for a given project type; and
• The Credit and Tracking System (CATS) to register offset projects, issue and track offset credits, and share key information through Canada's GHG Offset Credit System Public Registry.

Only projects following a federal offset protocol included in the Compendium and meeting all requirements outlined in the Regulations can generate GHG reductions for which federal offset credits may be issued under the Regulations.

1.0 Introduction

Methane (CH₄) emissions from livestock manure storage are primarily generated by the anaerobic decomposition of liquid manure in the storage system. Implementation of manure treatment systems (MTS) for the stored manure ensures that CH₄ emissions are reduced either by converting manure CH₄ into biogenic carbon dioxide (CO₂) or by reducing manure CH₄ production during storage.

The Reducing Manure Methane Emissions federal offset protocol will be intended for use by a proponent undertaking a project that treat manure with one or more eligible MTS which generate greenhouse gas (GHG) emission reductions for which federal offset credits may be issued under the Canadian Greenhouse Gas Offset Credit System Regulations (Regulations). The following are eligible project activities:

• Installation and use of a chemical treatment system using acidification to reduce manure CH₄ production during storage of the acidified liquid sludge;
• Installation and use of a mechanical treatment system separating manure in two outputs: a solid sludge and a liquid sludge. The solid sludge will be stored aerobically, producing low levels of CH₄. The liquid sludge will have lower organic content and so will produce lower levels of CH₄ emissions than raw manure when stored in anaerobic storage; and
• Installation and use of an anaerobic digestion (AD) system allowing the recovery and destruction of the produced manure CH₄ through a flare or a device to use the biogas for energy generation, instead of being passively released to the atmosphere.

The proponent must follow the methodology and requirements set out in this protocol, including those to quantify and report GHG emission reductions generated by eligible project activities. The requirements contained in this protocol are part of the Regulations and must be read in conjunction with provisions in the Regulations.

This protocol is designed to ensure a project generates GHG emission reductions that are real, additional, quantified, verified, unique and permanent. The protocol is also developed in accordance with the principles of ISO 14064-2:2019 Greenhouse gases – Part 2 – Specification with guidance at the project level for quantification, monitoring and reporting greenhouse gas emission reductions or removal enhancements to ensure reported GHG emission reductions generated as a result of implementing a project are relevant, complete, consistent, accurate, transparent, and conservative.

GHG emission reductions generated by a project under this protocol can only result from reduced or avoided CH₄ emissions achieved through the treatment of eligible manure within the project site via chemical, mechanical, AD systems or a combination of these systems.

Projects that use biogas produced from manure by an AD system to generate energy may reduce GHG emissions from fossil fuel combustion. While this activity is encouraged, GHG emission reductions from fossil fuel displacement (i.e. fuel switching) are not additional, as the emission sources are subject to pricing mechanisms for GHG emissions. Therefore, such GHG emission reductions are not eligible for federal offset credit issuance and they are not included in the quantification of GHG emission reductions under this protocol. Proponents may be able to generate credits for this activity under other crediting mechanisms, such as the Clean Fuel Regulations. However, proponents are responsible for ensuring that any GHG emission reductions credited under Canada's GHG Offset Credit System are unique, that is, they are not credited under another offset program or another GHG reduction mechanism.

2.0 Terms and Definitions

Act

means the Greenhouse Gas Pollution Pricing Act (GGPPA).

Adjacent destruction facility

means a facility adjacent to the manure treatment site (MTS) where manure CH₄ is destroyed in an eligible destruction device owned by an end user or the proponent.

Anaerobic digestion (AD) MTS

means an MTS engineered to maximize anaerobic CH₄ production, such as a heated tank or adding enzymes. Covered manure storage structures with passive CH₄ production and capture are not considered AD systems under this protocol.

Anaerobic storage

means the storage of liquid manure or liquid sludge under anaerobic conditions, in a storage structure with a depth equal to or more than 1 m, such as an earthen basin or lagoon, a tank or a deep pit.

Biogenic carbon dioxide (CO₂)

means CO₂ emissions resulting from the decomposition or destruction of manure, including those produced from the destruction of manure CH₄; they are considered to be a natural part of the carbon cycle.

Centralized digester

means an AD MTS that receives and treats manure from more than one livestock operation.

Chemical MTS

means an MTS which uses a chemical agent, such as a strong acid, added to the liquid manure or sludge to suppress CH₄ production under anaerobic storage. The chemical agent may be added to the manure or sludge in the storage structure or prior to the manure or sludge entering the storage structure. This excludes systems adding the chemical agent post-storage such as during land application.

Deep bedding

means organic material, including coarse solid sludge, used as bedding for the purpose of absorbing moisture from fresh livestock excreta, typically for several months.

Destruction

means the combustion of manure biogas and the resulting conversion of manure CH₄ into biogenic CO₂.

Eligible destruction device

means a device, listed in Table 1, that can destroy manure CH₄ and generate GHG emission reductions for which offset credits can be issued.

Feedstock

means any organic material treated by a project MTS.

Fugitive emissions

means intentional and unintentional releases of GHGs from joints, seals, packing, gaskets, and other components within AD systems, including all processing, piping, treatment equipment and destruction devices.

Global warming potential (GWP)

means a metric representing the ability of a GHG to trap heat in the atmosphere compared to CO₂, as provided in Column 2 of Schedule 3 to the Act.

Livestock operation

means the facility, including the land and buildings, used for the raising of livestock and the storage of livestock manure.

Liquid manure

means livestock excreta which contains less than 20% of dry matter content. It might include addition of water and/or organic or inorganic bedding material such as straw or sand.

Liquid sludge

means the output of an MTS which contains less than 20% of dry matter content. It might include the liquid phase following a mechanical MTS, the liquid output of an AD MTS also known as digestate, or the acidified output from a chemical MTS.

Liquid storage

means the storage of liquid manure or sludge in a structure for more than 24 hours.

Manure biogas

means a gaseous mixture that is recovered from the decomposition of manure in anaerobic storage, that consists primarily of CH₄ and biogenic CO₂ and contains other constituents that prevent it from meeting the standard for injection into a natural gas pipeline. Biogas can be used as a fuel, for example to generate heat or electricity.

Manure methane (manure CH₄)

means the CH₄ portion of manure biogas, generated by the anaerobic decomposition of manure stored in an anaerobic storage structure.

Manure treatment site

means an identifiable area of public or private land where a project MTS and all supporting buildings and infrastructure are located. Manure or sludge storage systems, however, may be located outside of the manure treatment site, such as at the site of other livestock operations.

Manure treatment system (MTS)

means a system preventing the emission of manure CH₄ to the atmosphere, either by converting manure CH₄ into biogenic carbon dioxide (CO₂) or by reducing manure CH₄ production during storage. The MTS includes all equipment operated for the treatment of manure and associated outputs such as presses, filters, acidification tanks, digesters, sludge storages, biogas purification systems, and eligible destruction devices.

Mechanical MTS

means an MTS separating the liquid and solid phases of manure by mechanical means such as a filter, press, centrifuge, or other mechanical separation methods. For example, a mechanical MTS may consist in a system allowing only the separation of coarse solids or a system allowing the separation of fine solids (also known as nutrient recovery systems).

Project site

means the area, contiguous or non-contiguous, where the following are located: all storage sites, the manure treatment site and supporting buildings and infrastructure related to biogas destruction, including adjacent destruction facilities.

Project MTS

means an MTS installed and operated for the purpose of implementing the project, which is either a new system or an existing system that was previously treating feedstock that included eligible manure.

Regulations

means the Canadian Greenhouse Gas Offset Credit System Regulations.

Renewable natural gas (RNG)

means gas that meets the standard for injection into a natural gas pipeline and that is either synthetic natural gas derived from biomass or gas derived from the processing of biogas.

Solid manure

means livestock excreta which contains at least 20% of dry matter content due to the presence of organic or inorganic bedding material or loss of moisture by evaporation.

Solid sludge

means the output of an MTS which contains at least 20% of dry matter content. It may include the coarse solids and fine solids phase from a mechanical MTS.

Solid storage

means the storage of solid manure or solid sludge for more than 24 hours in a structure for more than 24h, such as an exercise yard, a static pile, or an in-vessel compost.

Static pile

means a structure to store solid manure or solid sludge with or without forced aeration but no mixing or turning of the pile.

Storage site

means a storage structure adjacent or not to the manure treatment site where solid or liquid sludge from the project MTS is stored for a period of more than 24 hours, or a storage structure adjacent or not to the manure treatment site used to store eligible manure in the baseline scenario.

3.0 Baseline Scenario

The baseline scenario for the project is the release of manure CH₄ to the atmosphere from anaerobic storage of liquid manure or liquid sludge in the absence of the project.

3.1 Baseline conditions

For a project to be eligible under this protocol, at least one of the following baseline conditions must be met at the project site before the project start date:

• There is one or more existing livestock operations each managing manure in anaerobic storage for two years or more prior to the project start date;
• There is one or more existing livestock operations each managing manure in anaerobic storage for less than two years and in which the livestock raised was dairy cattle or swine; or
• There is no existing livestock operation.

In addition, for any existing livestock operation managing manure in anaerobic storage at the project site, the following baseline conditions must be met before the project start date:

• The biogas from anaerobic storage was not recovered, destroyed or treated in any way, including by biofilters, for at least two years prior to the project start date; and
• Manure in anaerobic storage was not acidified;
  • However, this condition does not have to be met if the manure previously stored is completely evacuated from the storage structure before the project start date and excluded from the project.

4.0 Project Scenario

4.1 Project conditions

To be eligible under this protocol, a project must meet the following project conditions on and after the project start date:

• When there is no existing livestock operation before the project start date, livestock producing manure treated by the project is dairy cattle or swine;
• Within the project site, eligible manure, as determined in Section 4.2, is treated by at least one project MTS of the types listed in Section 4.3;
• When eligible manure is sent to a chemical MTS:
  • Eligible manure is acidified to a pH of 5.5 or less, and
  • Acidification is achieved via the addition of sulfuric acid exclusively; and
• When eligible manure is sent to an AD MTS, CH₄ from eligible manure is recovered and destroyed in one or more eligible destruction devices listed in Table 1.

The project MTS may treat eligible manure originating from more than one livestock operation (e.g. centralized AD system).

The project MTS may treat any feedstock, but only GHG emission reductions generated from eligible manure are eligible for the issuance of federal offset credits under this protocol.

4.2 Eligible manure

Manure that is to be treated in a project must meet the following conditions to be eligible under this protocol:

• For any existing livestock operation, the manure is sourced from a livestock operation meeting the baseline conditions in Section 3.1;
• Manure was not mixed with any other organic or inorganic material before storage, except for animal bedding;
• For manure treated by one or more pre-existing AD or mechanical MTS, (i.e., in operation prior to the project start date), and where such MTSs are continuing to operate, only the liquid sludge after treatment by the pre-existing MTSs is eligible manure; and
• For any new livestock operation, manure is sourced from dairy cattle or swine.

4.3 Eligible project activities

Eligible project activities are the treatment of eligible manure in at least one of the following MTS types operated within the project site:

• A chemical MTS;
• A mechanical MTS;
• An AD MTS.

4.3.1 Eligible project activities specific to an AD MTS

In cases where an AD MTS is operated as part of the project, eligible project activities are:

• Treatment, purification, and upgrading of manure CH₄ recovered from within the project site; and
• Operation of one or more eligible destruction devices listed in Table 1 for the destruction of manure CH₄ recovered from within the project site.

Eligible destruction devices can be installed for the purposes of the project or can have been installed and operated prior to the project start date, including prior to January 1, 2017.

A project may use eligible destruction devices located at facilities outside of the manure treatment site provided that the eligible destruction devices are not a flare (open or enclosed). If the owner of the destruction devices is not the proponent, the proponent must have an agreement with the biogas end-user which specifies the following:

• The proponent is authorized to use the destruction device and the related equipment for the purpose of implementing the project;
• No federal offset credits issued for the GHG emission reductions generated by the project will be claimed by the end user; and
• No credits will be attributed under another GHG reduction mechanism to the end user for the GHG emission reductions generated by the project.

Table 1: Eligible destruction devices

Type	Description
Open flare	A device with a pilot flame at the top of a vertical stack that is exposed to atmosphere that combusts and destroys a gas.
Enclosed flare	A device with an insulated cylinder stack surrounding a burner manifold and combustion/cooling air louvers that combusts and destroys a gas.
Boiler	A device that combusts a fuel in order to heat a fluid, such as water or leachate, generating vapour that provides thermal energy for various purposes.
Turbine (micro or large)	A device that compresses air to combust with a fuel in order to produce expanding gas that turns turbine blades, generating mechanical energy that can be harnessed by a load (e.g. a generator producing electricity).
Internal combustion engine (stationary or mobile)	A device that compresses and combusts an air-fuel mixture in a cylinder in order to produce expanding gas that moves a piston and crankshaft, generating rotary mechanical energy that can be harnessed by a load (e.g. a generator producing electricity).
Station for direct injection of upgraded biogas into a natural gas networkFootnote 1	A device that monitors and prepares upgraded biogas for injection into a natural gas network; this can include odourizing the gas, metering the flow, regulating the pressure, and monitoring the chemical composition prior to injection.
Station for compression or liquefaction of upgraded biogas prior to transport and injection into a natural gas network	A device that compresses or liquefies upgraded biogas for transport to a station for its injection into a natural gas network (see above).

5.0 Additionality

5.1 Legal additionality

GHG emission reductions generated by a project must not occur as a result of federal, provincial or territorial laws (including regulations), municipal by-laws, or any other legally binding mandates. This includes legal requirements to control the release of manure biogas or to treat all or a portion of manure to reduce GHG emissions from the livestock operation or for reasons related or not to GHG emissions, such as odour control or other pollutant control (e.g. requirements to use biofilters or chemical treatments).

If at any time after project registration the GHG emission reductions generated by the project become required by law or the result of a legal requirement, the GHG emission reductions will no longer be additional and, therefore, offset credits can only be issued for GHG emission reductions generated up to the date immediately preceding the date on which the law or the legal requirement comes into force.

5.2 Provincial or federal pricing mechanisms for GHG emissions

Any emission sources that are included in a facility's GHG emissions reported under a federal, provincial or territorial pricing mechanism for GHG emissions are not eligible for federal offset credits.

GHG emission reductions resulting from reducing or displacing fuels subject to a regulatory charge on fuel or another pricing mechanism for GHG emissions are also not eligible for federal offset credits.

6.0 General requirements

6.1 Project start date

The start date of a project corresponds to the first day the project MTS treats eligible manure. To be eligible under this protocol, a project must have a start date that is on or after January 1, 2017.

Some MTS components may have been in operation prior to January 1, 2017, such as feedstock receiving structures and sludge storage systems, but these components can not have been used as part of the project MTS prior to the project start date.

6.2 Project site location and geographic boundaries

The proponent must document and report the location and geographic boundaries of the project site and submit a site plan. The site plan must show and clearly label the following:

• The location of all the components of the project site, including:
  • The manure treatment site,
  • All storage sites used to store manure in the baseline scenario or sludge in the project scenario, including storage sites outside of the manure treatment site, and
  • Any adjacent destruction facility destroying biogas generated by the project MTS, if applicable; and
• The location and arrangement of all project MTS components, which may include:
  • MTS sludge storage structures,
  • biogas treatment equipment,
  • biogas purification and upgrading equipment,
  • eligible destruction devices,
  • gas measuring devices, and
  • any other equipment associated with the SSRs within the project GHG boundary (Section 7.0).

The geographic boundary of the project site cannot change after the first reporting period, but project activities can expand within the project site's geographic boundary. Any changes to the site plan must be communicated as specified in the Regulations.

6.3 Environmental and social safeguards

6.3.1 Compliance with applicable environmental legal requirements

The proponent must ensure that the project activities comply with all applicable laws (including regulations), operating permits, municipal by-laws, and other legal requirements applicable to the project site, including such as those related to minimizing odour, protecting air and water quality, and managing nutrients from manure.

The proponent must also ensure that any output of the project MTS is disposed of in accordance with all applicable laws, including relevant federal and provincial or territorial regulations, and municipal by-laws. Disposal includes but is not limited to land application and discharge into water bodies.

6.3.2 Land application of acidified liquid sludge

To prevent negative impacts^{Footnote 2} of land application of acidified liquid sludge, the proponent must ensure that all lands receiving acidified liquid sludge during a reporting period are covered by a crop nutrient plan or similar fertilizer management document completed by a Professional Agrologist (P.Ag.) or Certified Crop Advisor (CCA). The plan or document must account for the lower pH and higher nitrogen content of acidified liquid sludge and must indicate:

• With regard to the pH, one of the following:
  • That continued application of acidified liquid sludge is unlikely to result in soil acidification and associated declines in crop productivity for the duration of the crediting period, or
  • Where the potential for soil acidification exists, that it can be managed through the use of other soil amendments (e.g. lime) or adjustments to manure application; and
• That the higher nitrogen content of acidified sludge is accounted for and supplemental fertilizer amounts are adjusted respectively.

The proponent must ensure that recommendations in the plan or document prescribed above with regard to managing soil acidification risks and nitrogen content are implemented.

7.0 Project GHG boundary

The project GHG boundary (Figure 1 ) contains the GHG SSRs that must be included or excluded by the proponent in the baseline and project scenarios to determine the GHG emission reductions generated by the project.

Table 2 provides additional details on the SSRs identified for the baseline and project scenarios, as well as justification for their inclusion or exclusion in the quantification of GHG emission reductions. The proponent must assess each of the “included” SSRs that are relevant to the specific activities taking place in the baseline and project scenarios.

Three GHGs are relevant to the SSRs in this protocol: carbon dioxide (CO₂), methane (CH₄), and nitrous oxide (N₂O). CO₂ emissions from the decomposition of manure and from the destruction of manure CH₄ are considered biogenic and are excluded from the quantification of GHG emission reductions under this protocol.

Figure 1: Illustration of the project GHG boundary

Table 2: Details on baseline and project scenario SSRs

SSR	Title	Description	Type	Baseline or project scenario	GHGFootnote 3	Included or excluded
1	Enteric Fermentation	Enteric fermentation of the feed consumed by cattle.	Related	Baseline (B1) Project (P1)	CH4	Excluded: GHG emissions from this source are assumed to be the same in both the baseline and project scenarios.
2	Manure Collection	Combustion of fossil fuels or consumption of grid electricity for the operation the manure collection system.	Related	Baseline (B2) Project (P2)	CO2, CH4, N2O	Excluded: GHG emissions from this source are assumed to be the same in both the baseline and project scenarios.
3	Manure Transport	Combustion of fossil fuels in vehicles used to transport manure to the storage or treatment site.	Controlled	Project (P3)	CO2, CH4, N2O	Included: Project activities are susceptible to significantly increase these GHG emissions. Quantified based on fossil fuel usage, using Equation 9.
4	Chemical Production	Combustion of fossil fuels and process emissions for the production of chemicals used in a project chemical MTS.	Affected	Project (P4)	CO2, CH4, N2O	Excluded: GHG emissions from this source are negligible.
5	Chemical Transport	Combustion of fossil fuels in vehicles used to transport chemicals from the point of retail to the site of the project chemical MTS.	Controlled	Project (P5)	CO2, CH4, N2O	Included: Project activities are susceptible to significantly increase these GHG emissions. Quantified based on fossil fuel usage, using Equation 9.
6	Chemical Treatment	Combustion of fossil fuels or consumption of grid electricity for the operation of the project chemical MTS.	Fossil Fuels: Controlled Electricity: Related	Project (P6)	CO2, CH4, N2O	Included: Quantified based on energy usage, using Equation 9 and/or Equation 10.
7	Mechanical Treatment	Combustion of fossil fuels or consumption of grid electricity for the operation of the project mechanical MTS.	Fossil Fuels: Controlled Electricity: Related	Project (P7)	CO2, CH4, N2O	Included: Quantified based on energy usage, using Equation 9 and/or Equation 10.
8	Sludge Transport	Combustion of fossil fuels in vehicles used to transport sludge to the storage site or direct land application.	Controlled	Project (P8)	CO2, CH4, N2O	Included: Quantified based on fossil fuel usage, using Equation 9.
9	Manure / Sludge Storage	Manure or sludge decomposition during storage.	Controlled	Baseline (B9) Project (P9)	CH4	Included: Quantified based on measured VS content in manure, using Equation 2 and in sludge as per Section 8.2.1.
					N2O	Excluded: GHG emissions from this source are likely to be similar or lower in the project scenario and are conservatively excluded.
10	Land Application	Combustion of fossil fuels in equipment used to apply manure or sludge to the land and emissions from manure or sludge decomposition in the soil.	Related	Baseline (B10) Project (P10)	CO2, CH4, N2O	Excluded: GHG emissions from this source are assumed to be similar in both the baseline and project scenarios. Acidified liquid sludge from a chemical MTS has a higher nitrogen content than non-acidified manure and might lead to increased N2O emissions from land application. The risk of increased N2O emissions from acidified sludge is addressed through the crop nutrient plan or similar fertilizer management document prescribed in section 6.3.2.
11	Anaerobic Digestion	Combustion of fossil fuels or consumption of grid electricity for the operation of the project AD MTS.	Fossil Fuels: Controlled Electricity: Related	Project (P11)	CO2, CH4, N2O	Included: Quantified base on energy usage, using Equation 9 and/or Equation 10.
12	Venting and leaks	Release of biogas due to continuous leaks in the AD system and emergency venting.	Controlled	Project (P12)	CH4	Included: Quantified based on a default or site-specific rate, using Equation 12 and Equation 16 if applicable.
					N2O	Excluded: N2O emissions from biogas leaks are negligible.
13	Biogas destruction - Flare	Destruction of biogas in an open or enclosed flare, as per Table 1 .	Controlled	Project (P13)	CH4, N2O	Included: Quantified based on undestroyed biogas CH4 and N2O from the destruction of biogas in a flare, using Equation 17 .
14	Biogas destruction – other devices	Destruction of biogas in a destruction device other than a flare, as per Table 1 .	Controlled	Project (P14)	CH4, N2O	Included: Quantified based on undestroyed biogas CH4 and N2O from the destruction of biogas in a destruction device, using Equation 17 .
15	Supplemental fuel combustion – Flare	Combustion of supplemental fossil fuel to support the operation of an open or enclosed flare.	Controlled	Project (P15)	CO2, CH4, N2O	Included: Quantified based on combustion of supplemental fossil fuel in a flare, using Equation 11 .
16	Use of thermal energy or power	Displacement of GHG emissions from the use off biogas-generated thermal energy or power	Related	Project (P16)	CO2, CH4, N2O	Excluded: These GHG emissions are subject to federal or provincial pricing mechanisms for GHG emissions and are not eligible for offset credits.

8.0 Quantification methodology

This section contains the quantification methodology that the proponent must follow to quantify baseline and project scenario GHG emissions, which are subsequently used to quantify the GHG emission reductions generated by the project.

Baseline scenario GHG emissions are the GHG emissions that would have occurred in the absence of a project, quantified based on SSRs within the project GHG boundary. Project scenario GHG emissions are the actual GHG emissions that occur from SSRs within the project GHG boundary. The GHG emission reductions generated by the project are quantified by deducting the project scenario GHG emissions from the baseline scenario GHG emissions as outlined in Section 8.4.

Raw data must be converted to align with the units presented in the quantification methodology, if necessary. Some emission factors and reference values that must be used for the quantification are provided in the Emission Factors and Reference Values document or in tables in Schedule A.

The quantification of both baseline and project scenario GHG emissions must include all GHG emissions that were likely to occur in the absence of the project (baseline scenario) and did occur (project scenario) during the reporting period and must include sub-totals in tonnes of CO₂ equivalent (t CO₂e) for each full or partial calendar year to support issuance of the resulting offset credits by calendar year.

8.1 Baseline scenario GHG emissions

The proponent must use Equation 1 and the subsequent equations in this section to quantify the baseline scenario GHG emissions for each full or partial calendar year covered by the reporting period, based on the included SSRs outlined in Table 2.

This protocol quantifies the baseline scenario GHG emissions through the use of a dynamic baseline approach based on volatile solids (VS) measurements in manure that is to be treated in the project scenario, instead of modelling the GHG emissions based on livestock head count.

Equation 1: Baseline scenario GHG emissions

$${\mathrm{BE}}_{\mathrm{C}}=\sum _{\mathrm{i}}^{\mathrm{n}}{\mathrm{BSE}}_{\mathrm{i}}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4}$$

Parameter	Description	Units
BEC	Baseline scenario GHG emissions during a calendar year covered by the reporting period	t CO2e
BSEi	Baseline CH4 emissions from anaerobic storage of manure from the livestock operation, i, during a calendar year covered by the reporting period, as per Equation 2	t CH4
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
n	Number of livestock operations from which eligible manure is sourced during a calendar year covered by the reporting period	unitless
i	Livestock operation	unitless

8.1.1 Baseline scenario CH₄ emissions from manure anaerobic storage

The proponent must use Equation 2 to quantify baseline scenario CH₄ emissions from manure anaerobic storage based on VS content in manure that is to be treated by the project MTS, measured accordingly to Section 9.1.2, and a site-specific methane conversion factor (MCF), calculated according to Section 9.1.3.

Equation 2: Baseline scenario CH₄ emissions from manure anaerobic storage

$${\mathrm{BSE}}_{\mathrm{i}}=\sum _{\mathrm{m}}^{\mathrm{M}}({\mathrm{QM}}_{\mathrm{i},\mathrm{m}}\times {\mathrm{VS}}_{\mathrm{source},\mathrm{i},\mathrm{m}})\times {\mathrm{B}}_{0,\mathrm{i}}\times \mathrm{MCF}\times \frac{{\rho }_{{\mathrm{CH}}_4}}{1000}$$

Parameter	Description	Units
BSEi	Baseline scenario CH4 emissions from anaerobic storage of manure from a livestock operation, i, during a calendar year covered by the reporting period	t CH4
QMi,m	Quantity of manure from livestock operation, i, that is to be treated by the project MTS in the project scenario during the month, m	t
VSsource,i,m	VS measured in manure from livestock operation, i, that is to be treated by the project MTS in the project scenario during the month, m, before mixing with any other organic material	kg VS/t manure
B0,i	Maximum CH4 producing potential for manure, as set out in Table A2	m3 CH4/kg VS
MCF	Methane conversion factor, determined according to Section 9.1.3	unitless
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
1000	Conversion factor, kilograms to tonnes	kg/t
M	Number of months in the full or partial calendar year covered by the reporting period	unitless
m	Month	unitless

If the livestock operation includes more than one livestock type, B₀ from the livestock type producing the largest quantity of manure on the livestock operation must be used.

8.2 Project scenario GHG emissions

The proponent must use Equation 3 and the subsequent equations in this section to quantify the project scenario GHG emissions for each full or partial calendar year covered by the reporting period, based on the included SSRs outlined in Table 2.

The project scenario GHG emissions correspond to the GHG emissions attributed to:

• The storage of liquid and solid sludge (SSR P9), quantified as per Section 8.2.1;
• Energy used for the operation of the project MTS (SSR P6, P7 and P11);
• The transport of manure (SSR P3), sludge (SSR P8) and chemicals (SSR P5), if applicable, quantified as per Section 8.2.2;
• Supplemental fossil fuel used to support the operation of a flare (SSR P15), if applicable, quantified as per Section 8.2.2; and
• Fugitive emissions including emergency venting and leaks (SSR P12), and the destruction of biogas in eligible destruction devices, if the project includes an AD MTS (SSR P13 and P14), quantified as per Section 8.2.3.

If the proponent has registered an AD MTS project in Canada's GHG Offset Credit System and the production facility where this project is implemented has been registered under the Clean Fuel Regulations (CFR), the proponent must not seek to be issued federal offset credits with respect to the manure CH₄ emission reductions generated by the project if the carbon intensity (CI) of the low-CI fuel (e.g. renewable natural gas (RNG) or biogas) determined under the CFR takes into account those reductions. In cases where federal offset credits are sought for manure CH₄ emission reductions^{Footnote 4}, the proponent:

• Must ensure that manure CH₄ emission reductions (or manure CH₄ avoided emissions, as per the CFR) are not taken into account in the CI of the low-CI fuel determined under the CFR; and
• May report project scenario GHG emissions (e.g. emissions from the digestate) of the offset project as zero as these emissions must be included in the CI determined under CFR^{Footnote 5}.

Equation 3: Project scenario GHG emissions

$${\mathrm{PE}}_{\mathrm{C}}={\mathrm{LS}}_{\mathrm{C}}+{\mathrm{SS}}_{\mathrm{C}}+{\mathrm{FF}}_{\mathrm{C}}+{\mathrm{EL}}_{\mathrm{C}}+{\mathrm{FF}}_{\mathrm{Flare},\mathrm{C}}+{\mathrm{FE}}_{\mathrm{C}}$$

Parameter	Description	Units
PEC	Project scenario GHG emissions during a calendar year covered by the reporting period	t CO2e
LSC	GHG emissions from liquid sludge stored in the project scenario (SSR P9) during a calendar year covered by the reporting period, as per Equation 4	t CO2e
SSC	GHG emissions from solid sludge stored in the project scenario, if applicable, (SSR P9) during a calendar year covered by the reporting period, as per Equation 6 or Equation 7	t CO2e
FFC	GHG emissions from the use of fossil fuels to transport of manure (SSR P3), chemicals (SSR P5) and sludge (SSR P8) and the operation of the project MTS (SSR P6, P7 and P11) during a calendar year covered by the reporting period, as per Equation 9	t CO2e
ELC	GHG emissions from the use of grid electricity to operate the project MTS (SSR P6, P7 and P11) during a calendar year covered by the reporting period, as per Equation 10	t CO2e
FFFlare,C	GHG emissions from the use of supplemental fossil fuels to support the operation of a flare (SSR P15) during a calendar year covered by the reporting period, as per Equation 11	t CO2e
FEC	Fugitive GHG emissions from emergency venting, leaks in the project MTS (SSR P12), and the incomplete destruction of biogas in eligible destruction devices (SSR P13 and P14) during a calendar year covered by the reporting period, if the project site includes an AD MTS, as per Equation 12	t CO2e
C	Calendar year	unitless

8.2.1 GHG emissions from the storage of all project MTS sludge types in the project scenario

The proponent must quantify GHG emissions from the storage of all sludge types in the project scenario identified in Table A3 in Schedule A.

If a project includes more than one project MTS, the proponent must include all sludge types entering a storage type. This excludes sludge types directly treated by another project MTS without being stored.

The proponent must quantify GHG emissions attributed to the storage of liquid non-acidified and liquid acidified sludge using Equation 4 and Equation 5. The proponent must determine the GHG emissions from solid sludge as per Equation 6 for all type of solid sludge storage. Alternatively, if the storage type is static piles or other types of composting and the proponent measures the VS of the sludge prior to mechanical separation, Equation 7 and Equation 8 may be used to determine the GHG emissions from the solid sludge.

In the case of chemical treatment, the proponent must use VS_Source in Equation 2 to replace VS_Sludge in Equation 4. Sludge that is temporarily stored for less than 24h may be excluded from the quantification.

Equation 4: GHG emissions from liquid sludge stored anaerobically in the project scenario

$${\mathrm{LS}}_{\mathrm{C}}=\sum _{\mathrm{i}}^{\mathrm{n}}(\sum _{\mathrm{m}}^{\mathrm{M}}({\mathrm{QLS}}_{\mathrm{m}}\times {\mathrm{VS}}_{\mathrm{Sludge},\mathrm{m}})\times {\mathrm{B}}_{0,\mathrm{Average}}\times \mathrm{MCF}\times {\mathrm{EF}}_{\mathrm{Sludge},{\mathrm{CH}}_4,\mathrm{i}}\times \frac{{\rho }_{{\mathrm{CH}}_4}}{1000}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4})$$

Parameter	Description	Units
LSC	GHG emissions from liquid sludge stored anaerobically in the project scenario during a calendar year covered by the reporting period	t CO2e
QLSm	Quantity of liquid sludge sent to storage during the month, m	t
VSSludge,m	VS measured during the month, m, from the liquid sludge stored anaerobically	kg/t manure
B0,Average	Average maximum CH4 producing potential for sludge, as per Equation 5	m3 CH4/kg VS
MCF	Methane conversion factor, determined according to Section 9.1.3	unitless
EFSludge,CH4,i	Storage CH4 emission factor for liquid sludge sent to anaerobic storage type i, as set out in Table A3	unitless
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
1000	Conversion factor, kilograms to tonnes	kg/t
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
n	Number of sludge storage types	unitless
i	Type of sludge storage, as set out in Table A3	unitless
M	Number of months during a calendar year covered by the reporting period	unitless
m	Month	unitless
C	Calendar year	unitless

For project sites treating manure from a single livestock operation, the proponent must use B₀ values as set out in Table A2. If the livestock operation includes more than one livestock type, B₀ from the livestock type producing the largest quantity of manure on the livestock operation must be used. For project MTS treating manure from multiple livestock operations, the proponent must determine a weighted average B₀, as per Equation 5.

Equation 5: Weighted average B₀ for projects treating manure from more than one type of livestock operation

$${\mathrm{B}}_{0,\mathrm{Average}}=\sum _{\mathrm{i}}^{\mathrm{n}}[{\mathrm{B}}_{0,\mathrm{i}}\times \frac{{\mathrm{QM}}_{\mathrm{i}}}{{\mathrm{QM}}_{\mathrm{Total}}}]$$

Parameter	Description	Units
B0,Average	Weighted average maximum CH4 producing potential for liquid sludge	m3 CH4/kg VS
B0,i	Maximum CH4 producing potential for livestock type, i, measured or selected from Table A2	m3 CH4/kg VS
QMi	Quantity of manure from livestock type, i, treated by the project MTS in the project scenario during the reporting period	t
QMTotal	Total quantity of manure from livestock type, i, treated by the project MTS in the project scenario during the reporting period	t
n	Number of livestock type from which manure is sourced during the reporting period	unitless
i	Livestock type, as per Table A2	unitless

Equation 6: GHG emissions from solid sludge stored in the project scenario

$${\mathrm{SS}}_{\mathrm{C}}=\sum _{\mathrm{i}}^{\mathrm{n}}[(\frac{{\mathrm{QSS}}_{\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{\mathrm{Sludge},{\mathrm{CH}}_4,\mathrm{i}}}{1000}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4})+(\frac{{\mathrm{QSS}}_{\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{\mathrm{Sludge},{\mathrm{N}}_2\mathrm{O},\mathrm{i}}}{1000}\times {\mathrm{GWP}}_{{\mathrm{N}}_2\mathrm{O}})]$$

Parameter	Description	Units
SSC	GHG emissions from solid sludge stored in the project scenario during a calendar year covered by the reporting period	t CO2e
QSSi,C	Quantity of solid sludge sent to storage, i, during a calendar year covered by the reporting period	t
EFSludge,CH4,i	Storage CH4 emission factor for solid sludge sent to storage, i, as set out in Table A3	kg CH4/t wet sludge
EFSludge,N2O,i	Storage N2O emission factor for solid sludge sent to storage, i, as set out in Table A3	kg N2O/t wet sludge
1000	Conversion factor, kilograms to tonnes	kg/t
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
GWPN2O	GWP of N2O, as provided in Column 2 of Schedule 3 to the Act	t CO2/t N2O
n	Number of sludge storage types	unitless
i	Type of sludge storage, as per Column 1 of Table A3	unitless

Equation 7: GHG emissions from solid sludge stored in the project scenario using VS measurement

$${\mathrm{SS}}_{\mathrm{C}}=\sum _{\mathrm{m}}^{\mathrm{M}}({\mathrm{QSS}}_{\mathrm{m}}\times {\mathrm{VS}}_{\mathrm{SS},\mathrm{m}})\times {\mathrm{B}}_{0,\mathrm{Average}}\times 0.02\times \frac{{\mathrm{\rho }}_{{\mathrm{CH}}_4}}{1000}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4}+(\frac{\sum _{\mathrm{m}}^{\mathrm{M}}\left({\mathrm{QSS}}_{\mathrm{m}}\right)\mathrm{\times }{\mathrm{EF}}_{\mathrm{Sludge},{\mathrm{N}}_2\mathrm{O}}}{1000}\times {\mathrm{GWP}}_{{\mathrm{N}}_2\mathrm{O}})$$

Parameter	Description	Units
SSC	GHG emissions from solid sludge stored in the project scenario during a calendar year covered by the reporting period	t CO2e
QSSm	Quantity of solid sludge sent to storage during the month, m	t
VSSS,m	VS of the solid sludge from the project mechanical MTS determined during the month, m, as per Equation 8	kg/t manure
B0,Average	Average maximum CH4 producing potential for sludge as per Equation 5	m3 CH4/kg VS
0.02	Methane conversion factor for solid sludge adopted from Intergovernmental Panel on Climate Change (IPCC)Footnote 6	Unitless
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
1000	Conversion factor, kilograms to tonnes	kg/t
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
GWPN2O	GWP of N2O, as provided in Column 2 of Schedule 3 to the Act	t CO2/t N2O
EFSludge,N2O	Storage N2O emission factor for solid sludge sent to storage solid storage, as set out in Table A3	kg N2O/t wet sludge
M	Number of months during a calendar year covered by the reporting period	unitless
m	Month	unitless
C	Calendar year	unitless

Equation 8: VS of the solid sludge from the project mechanical MTS

$${\mathrm{VS}}_{\mathrm{SS},\mathrm{m}}={\mathrm{VS}}_{\mathrm{LS},\mathrm{pre},\mathrm{m}}-{\mathrm{VS}}_{\mathrm{Sludge},\mathrm{m}}$$

Parameter	Description	Units
VSSS,m	VS from the project mechanical MTS determined during the month, m	kg/t manure
VSLS,pre,m	VS measured from the liquid sludge pre mechanical MTS during the month, m	kg/t manure
VSSludge,m	VS measured from the liquid sludge stored anaerobically, i.e. post mechanical MTS, during the month, m	kg/t manure

8.2.2 GHG emissions from fossil fuels and energy usage in the project scenario

The proponent must account for GHG emissions attributed to the use of fossil fuels or electricity for:

• The transport of manure from the livestock operation to the MTS (SSR P3);
• The transport of sludge, solid or liquid, from the MTS site to the storage site (SSR P8);
• The transport of sulfuric acid necessary for the operation of a chemical MTS, from the retail site to the project MTS (SSR P5);
• The operation of the project MTS, including collection equipment, biogas purification system and destruction system (SSR P6, P7 and P11); and
• The use of supplemental fuel to support the operation of the flare (SSR P15).

The proponent must use Equation 9 to quantify the GHG emissions from transport of manure, sludge and/or acid using the total distance during each full or partial calendar year and vehicle energy consumption data.

The proponent must use Equation 9 and Equation 10 to quantify the GHG emissions from the operation of the MTS, purification equipment, and destruction devices during each full or partial calendar year covered by the reporting period.

The proponent must use applicable equations corresponding to the energy inputs required for the operation of all project MTS and related equipment; these may include biodigesters, destruction devices (other than flares), equipment for the conveyance of biogas to an adjacent facility, equipment for the upgrading of biogas, compression or liquefaction, and injection of upgraded biogas into a natural gas network. If both fossil fuel and grid electricity are used for these purposes, the proponent must use the summation of Equation 9 and Equation 10 to quantify SSR P6, P7 and SSR P11.

Equation 9: GHG emissions attributed to the use of fossil fuels for the transport of manure, sludge and acid and the operation of all project MTS

$${\mathrm{FF}}_{\mathrm{C}}=\sum _{\mathrm{i}}^{\mathrm{n}}\left[\begin{array}{c}\left({\mathrm{FF}}_{\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{{\mathrm{CO}}_2,\mathrm{i}}\right)+\left({\mathrm{FF}}_{\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{{\mathrm{CH}}_4,\mathrm{i}}\mathrm{\times }{\mathrm{GWP}}_{{\mathrm{CH}}_4}\right)\\ +({\mathrm{FF}}_{\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{{\mathrm{N}}_2\mathrm{O},\mathrm{i}}\mathrm{\times }{\mathrm{GWP}}_{{\mathrm{N}}_2\mathrm{O}})\end{array}\right]\mathrm{÷}1000$$

Parameter	Description	Units
FFC	GHG emissions attributed to the use of fossil fuels for the transport of manure, sludge and acid, and the operation of the MTS during a calendar year covered by the reporting period (SSR P3, P5, P6, P7, P8 and P11)	t CO2e
FFi,C	Volume of fossil fuel, i, consumed by mobile and/or stationary equipment for the transport of manure and sludge, and for the operation of the MTS during a calendar year covered by the reporting period	m3
EFCO2,i	CO2 emission factor for fossil fuel, i, as set out in the Emission Factors and Reference Values document	kg CO2/m3
EFCH4,i	CH4 emission factor for fossil fuel, i, as set out in the Emission Factors and Reference Values document	kg CH4/m3
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
EFN2O,i	N2O emission factor for fossil fuel, i, as set out in the Emission Factors and Reference Values document	kg N2O/m3
GWPN2O	GWP of N2O, as provided in Column 2 of Schedule 3 to the Act	t CO2/t N2O
1000	Conversion factor, kilograms to tonnes	kg/t
n	Number of fossil fuel types	unitless
i	Type of fossil fuel	unitless

Equation 10: GHG emissions attributed to the use of grid electricity for the operation of all project MTS

$${\mathrm{EL}}_{\mathrm{C}}=\frac{\mathrm{EL}\mathrm{\times }{\mathrm{EF}}_{\mathrm{EL},\mathrm{GHG}}}{1000}$$

Parameter	Description	Units
ELC	GHG emissions attributed to the use of grid electricity for the operation of the MTS during a calendar year covered by the reporting period (SSR P6, P7 and P11)	t CO2e
EL	Grid electricity consumed by the MTS during a calendar year covered by the reporting period	MWh
EFEL,GHG	GHG consumption intensity emission factor for grid electricity from the project province or territory, as set out in the Emission Factors and Reference Values document	kg CO2e/MWh
1000	Conversion factor, kilograms to tonnes	kg/t

If a project MTS includes an open or enclosed flare, the proponent must use Equation 11 to quantify the GHG emissions from supplemental fossil fuel used to support the operation of a flare during each full or partial calendar year covered by the reporting period, which corresponds to SSR P14.

Equation 11: GHG emissions attributed to the use of supplemental fossil fuel to support the operation of a flare

$${\mathrm{FF}}_{\mathrm{Flare},\mathrm{C}}=\sum _{\mathrm{i}}^{\mathrm{n}}\left[\begin{array}{c}\left({\mathrm{FF}}_{\mathrm{supp},\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{{\mathrm{CO}}_2,\mathrm{i}}\right)\\ +({\mathrm{FF}}_{\mathrm{supp},\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{{\mathrm{CH}}_4,\mathrm{i}}\mathrm{\times }{\mathrm{\rho }}_{{\mathrm{CH}}_4}\mathrm{\times }(1-{\mathrm{DE}}_{{\mathrm{CH}}_4})\mathrm{\times }{\mathrm{GWP}}_{{\mathrm{CH}}_4})\\ +({\mathrm{FF}}_{\mathrm{supp},\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{{\mathrm{N}}_2\mathrm{O},\mathrm{i}}\mathrm{\times }{\mathrm{GWP}}_{{\mathrm{N}}_2\mathrm{O}})\end{array}\right]\mathrm{÷}1000$$

Parameter	Description	Units
FFFlare,C	GHG emissions attributed to the use of supplemental fossil fuels to support the operation of a flare during a calendar year covered by the reporting period (SSR P15)	t CO2e
FFsupp,i,C	Volume of supplemental fossil fuel, i, consumed by a flare during a calendar year covered by the reporting period	m3
EFCO2,i	CO2 emission factor for supplemental fossil fuel, i, as set out in the Emission Factors and Reference Values document	kg CO2/m3
FFCH4,i	Average CH4 content of supplemental fossil fuel, i, obtained from the supplier	m3 CH4/m3
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
DECH4	CH4 destruction efficiency of the flare, as set out in Table 4 or specific to the device	unitless
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
EFN2O,i	N2O emission factor for supplemental fossil fuel, i, as set out in the Emission Factors and Reference Values document	kg N2O/m3
GWPN2O	GWP of N2O, as provided in Column 2 of Schedule 3 to the Act	t CO2/t N2O
1000	Conversion factor, kilograms to tonnes	kg/t
n	Number of types of supplemental fossil fuels	unitless
i	Type of supplemental fossil fuel	unitless

8.2.3 Project GHG emissions from fugitive GHG emissions for AD MTS

If the project site includes an AD MTS, the proponent must quantify fugitive GHG emissions attributed to:

• Leaks occurring at any point in the AD MTS with the exclusion of tanks or platforms receiving feedstock, sludge storage tanks and destruction devices (SSR P12);
• Emergency venting where biogas is released to the atmosphere, determined by a zero or near zero flow to all the eligible destruction devices simultaneously when biogas storage is at maximum capacity (SSR P12); and
• Incomplete destruction of CH₄ and emissions of N₂O generated from the destruction of biogas or RNG in eligible destruction devices (SSR P13 and P14).

Equation 12: GHG emissions attributed to fugitive emissions

$${\mathrm{FE}}_{\mathrm{C}}={\mathrm{LK}}_{\mathrm{C}}+{\mathrm{EV}}_{\mathrm{C}}+{\mathrm{DBG}}_{\mathrm{GHG},\mathrm{C}}$$

Parameter	Description	Units
FEC	GHG emissions attributed to fugitive emissions in the project scenario during a calendar year covered by the reporting period	t CO2e
LKC	GHG emissions attributed to leaks from the MTS during a calendar year covered by the reporting period, as per Equation 13 (SSR P12)	t CO2e
EVC	GHG emissions attributed to emergency venting from the MTS during a calendar year covered by the reporting period, as per Equation 16 (SSR P12)	t CO2e
DBGGHG,C	GHG emissions attributed to the destruction of biogas in eligible destruction devices during a calendar year covered by the reporting period, as per Equation 17 (SSR P13 and 14)	t CO2e
C	Calendar year	unitless

The proponent must use Equation 13 to quantify GHG emissions attributed to leaks from the MTS. The proponent must use a leaks rate Equation 13 (LR) corresponding to the leaks survey activities conducted for each calendar year covered by the reporting period, as per Table 3. Leak surveys must be conducted in accordance with the requirements in section 9.1.4.

Equation 13: GHG emissions attributed to leaks from the AD MTS

$${\mathrm{LK}}_{\mathrm{C}}={\mathrm{MM}}_{\mathrm{C}}\times \mathrm{LR}\times \frac{{\mathrm{\rho }}_{{\mathrm{CH}}_4}}{1000}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4}$$

Parameter	Description	Units
LKC	GHG emissions attributed to leaks from the AD MTS during a calendar year covered by the reporting period (SSR P12)	t CO2e
MMC	Total volume of manure CH4 destroyed by eligible destruction devices during a calendar year covered by the reporting period, as per Equation 14	m3 CH4
LR	Leaks rate for an AD MTS, as per Table 3.	unitless
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
1000	Conversion factor, kilograms to tonnes	kg/t
C	Calendar year	unitless

Table 3: Leaks rate corresponding to the leaks survey activities

Leaks survey activities	Leaks rate (LR, unitless)
Leaks surveys not conducted each calendar year covered by the reporting period	0.05Footnote 7
Leaks surveys conducted each calendar year covered by the reporting period	0.005Footnote 8

Equation 14: Manure CH₄ destroyed by eligible destruction devices

$${\mathrm{MM}}_{\mathrm{i},\mathrm{C}}=\sum _{\mathrm{t}}^{\mathrm{n}}({\mathrm{BG}}_{\mathrm{t}}\times {\mathrm{MC}}_{\mathrm{t}})$$

Parameter	Description	Units
MMi,C	Total volume of manure CH4 destroyed by eligible destruction device, i, during a calendar year covered by the reporting period	m3 CH4
BGt	Corrected volume of biogas produced by the AD system during measurement period, t, as per automatic correction or Equation 15	m3 biogas
MCt	Average CH4 content of the biogas during measurement period, t	m3 CH4/m3 biogas
n	Number of measurement periods in a calendar year covered by the reporting period	unitless
t	Measurement period	unitless

All flow meter data must be corrected to the reference temperature and pressure conditions set out in Table A1 of Schedule A. If the flow meter does not automatically correct the measured volume to the reference temperature and pressure conditions, the proponent must quantify the corrected volume following Equation 15 . Equation 15 is not needed if the flow meter automatically corrects the volume.

Equation 15: Volume of biogas produced by the AD MTS, corrected to reference condition

$${\mathrm{BG}}_{\mathrm{t}}={\mathrm{BG}}_{\mathrm{UC},\mathrm{t}}\times \frac{{\mathrm{T}}_{\mathrm{ref}}}{{\mathrm{T}}_{\mathrm{t}}}\times \frac{{\mathrm{P}}_{\mathrm{t}}}{{\mathrm{P}}_{\mathrm{ref}}}$$

Parameter	Description	Units
BGt	Corrected volume of biogas produced by the AD system during measurement period, t	m3 biogas
BGUC,t	Uncorrected volume of biogas produced by the AD system during measurement period, t	m3 biogas
Tt	Measured temperature of the biogas for the measurement period, t	K
Tref	Reference temperature of the biogas, as set out in Table A1	K
Pt	Measured pressure of the biogas for the measurement period, t	kPa
Pref	Reference pressure of the biogas, as set out in Table A1	kPa

In the event of an emergency venting where biogas from the project AD MTS is released to the atmosphere, the proponent must use Equation 16 to quantify the CH₄ emissions corresponding to SSR P12.

Equation 16: GHG emissions attributed to emergency venting from the AD MTS

$${\mathrm{EV}}_{\mathrm{C}}=(\mathrm{BD}+{\mathrm{BG}}_{\mathrm{V}7}\times \mathrm{TV})\times {\mathrm{MC}}_{\mathrm{V}7}\times \frac{{\mathrm{\rho }}_{{\mathrm{CH}}_4}}{1000}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4}$$

Parameter	Description	Units
EVC	GHG emissions attributed to emergency venting from the project AD MTS during a calendar year covered by the reporting period (SSR P12)	t CO2e
BD	Maximum volume of biogas in the biodigester	m3 biogas
BGV7	Average flow of biogas during the 7 days preceding the emergency event	m3 biogas/h
TV	Duration of emergency venting event	h
MCV7	Average CH4 content of the biogas during the 7 days preceding the emergency event	m3 CH4/m3 biogas
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
1000	Conversion factor, kilograms to tonnes	kg/t
C	Calendar year	Unitless

The proponent must use Equation 17 to quantify GHG emissions attributed to the destruction of biogas in eligible destruction devices, which correspond to the undestroyed manure CH₄ and the N₂O emissions generated from the destruction of biogas during each full or partial calendar year covered by the reporting period, corresponding to SSR P13 and P14.

Equation 17: GHG emissions attributed to the destruction of biogas in eligible destruction devices

$${\mathrm{DBG}}_{\mathrm{GHG},\mathrm{C}}={\mathrm{DBG}}_{{\mathrm{CH}}_4,\mathrm{C}}+[\sum _{\mathrm{i}}^{\mathrm{n}}\left(\frac{{\mathrm{MM}}_{\mathrm{i},\mathrm{C}}\mathrm{\times }{\mathrm{EF}}_{\mathrm{BG},{\mathrm{N}}_2\mathrm{O},\mathrm{i}}}{1000}\right)\times {\mathrm{GWP}}_{{\mathrm{N}}_2\mathrm{O}}]$$

Parameter	Description	Units
DBGGHG,C	GHG emissions attributed to the destruction of biogas in eligible destruction devices during a calendar year covered by the reporting period (SSR P13 and P14)	t CO2e
DBGCH4,C	Undestroyed manure CH4 released to atmosphere during a calendar year covered by the reporting period based on the destruction efficiency of eligible destruction devices, as per Equation 18	t CO2e
MMi,C	Volume of manure CH4 destroyed by eligible destruction device(s), i, during a calendar year covered by the reporting period, as per Equation 14	m3 CH4
EFBG,N2O,i	N2O emission factor for the destruction of biogas in eligible destruction device, i, as set out in the Emission Factors and Reference Values document	kg N2O/m3 CH4
1000	Conversion factor, kilograms to tonnes	kg/t
GWPN2O	GWP of N2O, as provided in Column 2 of Schedule 3 to the Act	t CO2/t N2O
n	Number of eligible destruction devices	unitless
i	Eligible destruction device	unitless

Equation 18: Quantity of undestroyed manure CH₄ from eligible destruction devices

$${\mathrm{DBG}}_{{\mathrm{CH}}_4,\mathrm{C}}=\sum _{\mathrm{i}}^{\mathrm{n}}[{\mathrm{MM}}_{\mathrm{i},\mathrm{C}}\times (1-{\mathrm{DE}}_{{\mathrm{CH}}_4,\mathrm{I}})]\times \frac{{\mathrm{\rho }}_{{\mathrm{CH}}_4}}{1000}\times {\mathrm{GWP}}_{{\mathrm{CH}}_4}$$

Parameter	Description	Units
DBGCH4,C	Quantity of undestroyed manure CH4 released to atmosphere during a calendar year covered by the reporting period based on the destruction efficiency of eligible destruction devices	t CO2e
MMi,C	Volume of manure CH4 delivered to eligible destruction device, i, during a calendar year covered by the reporting period, as per Equation 14	m3 CH4
DECH4,i	CH4 destruction efficiency of eligible destruction device, i, as set out in Table 4 or specific to the device	unitless
ρCH4	Reference density of CH4, as set out in Table A1	kg CH4/m3 CH4
GWPCH4	GWP of CH4, as provided in Column 2 of Schedule 3 to the Act	t CO2/t CH4
1000	Conversion factor, kilograms to tonnes	kg/t
n	Number of eligible destruction devices	unitless
i	Eligible destruction device	unitless

The amount of manure CH₄ destroyed in each eligible destruction device is dependent on the CH₄ destruction efficiency for each device (DE_CH4). Table 4 sets out default CH₄ destruction efficiencies that can be used by the proponent for each eligible destruction device in the project.

The proponent may also determine a device-specific destruction efficiency for each eligible destruction device in the project. Testing for the device-specific destruction efficiency must be conducted each reporting period, and include at least three test runs, with the accepted final value being one standard deviation below the mean of the measured efficiencies.

Table 4: Default CH₄ destruction efficiencies by eligible destruction device (DE_CH4)

Eligible destruction device	Efficiency (DECH4)Footnote 9
Open flare	0.96
Enclosed flare	0.995
Boiler	0.98
Turbine (micro or large)	0.995
Internal combustion engine (stationary or mobile)	0.936
Station for direct injection of upgraded biogas into a natural gas network	0.98
Station for compression or liquefaction of upgraded biogas prior to transport and injection into a natural gas network	0.95

8.3 Leakage

A project that reduces the quantity of manure produced in the project scenario compared to the baseline scenario poses a leakage risk if GHG emission reductions are calculated on an absolute basis based on historical manure quantities. This form of leakage is avoided in this protocol by quantifying GHG emissions in the baseline scenario based on the quantity of manure that will be treated in the project scenario (i.e., using a dynamic baseline) to ensure functional equivalency between the baseline and project scenarios.

As a result, there is no leakage discount factor (which corresponds to variable Ci in the formula in subsection 20(2) of the Regulations) to be applied for the quantification of GHG emission reductions generated by a project undertaken under this protocol.

8.4 Project GHG emission reductions

The proponent must use Equation 19 to quantify the GHG emission reductions (ERC) generated by the project, which correspond to the GHG reductions determined in accordance with section 20 of the Regulations.

Equation 19: Project GHG emission reductions

$${\mathrm{ER}}_{\mathrm{C}}={\mathrm{BE}}_{\mathrm{C}}-{\mathrm{PE}}_{\mathrm{C}}$$

Parameter	Description	Units
ERC	Project GHG emission reductions during a calendar year covered by the reporting period	t CO2e
BEC	Baseline scenario GHG emissions during a calendar year covered by the reporting period, as per Equation 1	t CO2e
PEC	Project scenario GHG emissions during a calendar year covered by the reporting period, as per Equation 3	t CO2e
C	Calendar year	unitless

9.0 Measurement and data

9.1 Data collection

9.1.1 Manure and sludge quantity

The proponent must measure the quantity of eligible manure treated by the project MTS to determine SSR B9 emissions and the quantity of sludge produced by the project MTS to determine SSR P9 emissions.

If manure or sludge is measured by volume, the volume must be converted to mass using a density of 1 tonne/m³ for raw manure, raw AD sludge or acidified sludge. For manure mechanically separated in a pre-existing MTS or sludge from a project MTS, the density of liquid sludge must be measured every 3 months and the average density used to convert volume to mass.

9.1.2 VS content

The proponent must measure the VS content monthly in the following:

• In each source of eligible manure before mixing with any other non-eligible manure or organic material. 
  • Manure from different livestock operations may be pooled before measuring VS content if the livestock operations all raise the same livestock type as listed in column 1 of Table A2; and
• In liquid sludge after treatment by all project MTS, except for acidified sludge.

In addition to the two VS measures above, if the proponent chooses to use Equation 7 and Equation 8 to quantify GHG emissions from solid sludge stored in static piles or composting, and the project activity consists of an AD MTS followed by a mechanical MTS, VS content must be measured in the liquid sludge prior to entering the mechanical MTS.

Manure or sludge must be sampled from well-mixed manure before entering anaerobic storage. VS content must be analyzed following a recognized standard, such as the American Public Health Association (APHA) Standard Methods for the Examination of Water and Wastewater^{Footnote 10}.

9.1.3 Methane conversion factor (MCF)

The proponent must determine a site-specific MCF following the method in Annex 10A.3 of the IPCC 2019 guidelines^{Footnote 11} and using the following instructions for determining input values:

• Monthly air temperature must be sourced from the Government of Canada’s historical weather data using information from the weather station nearest to the manure treatment site^{Footnote 12};
• Manure removal may be set at once a year if the proponent can demonstrate manure removal occurred annually at the livestock operation for two years prior to the project start date. Otherwise, manure removal must be set at twice a year in May and October regardless of historical practice at the livestock operation. Manure removal frequency and timing must remain the same both in the baseline scenario and in the project scenario; and
• All other parameters must use the default values provided by the IPCC 2019 guidelines.

MCF may be determined for the whole project site or be specific to a livestock operation if manure removal frequency varies between livestock operations within a project site.

9.1.4 Leak rate

To be able to use the leak rate associated with leak surveys in Table 3, the proponent must conduct leak surveys according to the following requirements:

• Leak surveys must be conducted a minimum of every three months during the reporting period;
• Each leak survey must consist of extensive leak detection on all components of the project MTS from the digester to the inlet of associated eligible destruction devices;
• Measuring devices used for CH₄ leak detection must follow the requirements specified in Section 9.2.4.6; and
• A leak is defined as one of the following:
  • A reading of at least 500 ppmv of CH₄ concentration on an instrument listed in Section 9.2.4.6, or
  • A release of any concentration detected by means of an auditory method, an olfactory method or a visual method.

Any leak detected in a survey must be repaired and effective repairs must be demonstrated by a follow-up survey within 30 days of leak detection. The proponent must carry out leak surveys during the initial reporting period. Leak surveys are optional for all subsequent reporting periods.

9.2 Measuring devices

9.2.1 General measuring devices

All types of MTS must include at least one measuring device to measure the quantity of manure being treated by the MTS, by weight or volume, such as a flow meter, truck scales or volumetric sensors.

For manure separated by a pre-existing mechanical MTS, a density meter must be used to provide measurements every 3 months and averaged over the reporting period.

The quantity of grid electricity used for the operation of the MTS must be measured by permanent meters or determined using purchase records.

9.2.2 Measuring devices specific to a project chemical MTS

A chemical MTS must include a permanent pH meter that directly measures sludge pH at the outlet of the acidification system. Measurement frequency must be at least hourly with an average compiled daily.

9.2.3 Measuring devices specific to a project mechanical MTS

A mechanical MTS must include the following measuring devices:

• A flow meter or a scale to measure all sludge types by volume or weight at the frequency determined as per Table 5; and
• For sludge measured by volume, a density meter providing measurements every 3 months and averaged over the reporting period.

9.2.4 Measuring devices specific to a project AD MTS

9.2.4.1 Sludge measuring devices

A project AD MTS must include the following measuring devices to measure sludge attributes:

• A flow meter or a scale to measure all sludge types by volume or weight at the frequency determined as per Table 5; and
• For sludge measured by volume, a density meter providing measurements every 3 months and averaged over the reporting period.

9.2.4.2 Biogas flow meters

A project AD MTS must include a permanent flow meter that directly and separately measures the volume of biogas produced from the MTS and delivered to each individual eligible destruction device. Volume data must be converted into cubic metres (m³) to align with the quantification methodology in Section 8.0.

9.2.4.3 Biogas temperature and pressure gauges

If a flow meter automatically corrects the biogas volume to the reference temperature and pressure conditions set out in Schedule A, no additional temperature and pressure gauges are required.

If a flow meter does not automatically correct the biogas volume, permanent temperature and pressure gauges must be installed to measure temperature and pressure at the same measurement frequency as the uncorrected volume of biogas (Section 9.3). Biogas temperature and pressure must be measured under the same conditions (wet or dry basis) as the biogas volume.

The biogas volume data must be corrected from measured temperature and pressure conditions to the reference temperature and pressure conditions set out in Table A1 using Equation 15.

9.2.4.4 Methane analyzers

A project AD MTS must include a permanent methane analyzer or portable methane analyzer (e.g. gas chromatographs) that directly measures the CH₄ content in the biogas on a volumetric basis.

9.2.4.5 Arrangement of biogas measuring devices

Flow meters and methane analyzers must be arranged in such a way as to ensure the data is representative of the biogas produced and destroyed by the project.

Flow meters must be placed to separately measure the volume of biogas produced from within the project site and delivered to each individual eligible destruction device.

For a project with multiple eligible destruction devices:

• If the biogas is delivered to the eligible destruction devices from a common manifold or header upstream of the destruction devices, one methane analyzer may be placed to measure the CH₄ content of the biogas at that common manifold or header pipe;
• If the biogas is delivered to each eligible destruction device from separate manifolds or header pipes, a methane analyzer is required upstream of each individual destruction device.

Additionally, flow meters and methane analyzers must be placed to:

• Measure the volume and CH₄ content of the biogas before the introduction of any supplemental fossil fuel;
• Measure the volume of supplemental fossil fuel prior to its introduction; and
• Measure the volume and CH₄ content of the biogas produced from within the project site separately from any other fuel sources prior to the destruction of the biogas in eligible destruction devices at adjacent facilities.

Measuring devices must be arranged such that biogas CH₄ content is measured under the same conditions (wet or dry basis) as biogas volume, temperature and pressure. However, a moisture-removing component may separate a methane analyzer and a flow meter where the methane analyzer is placed upstream of the moisture-removing component (CH₄ content measured on a wet basis), and the flow meter is placed downstream of the moisture-removing component (biogas volume measured on a dry basis). A moisture-removing component must not separate a methane analyzer and flow meter in any other configuration other than previously described. Other devices or equipment that could change the biogas composition by volume must not separate a methane analyzer and a flow meter.

9.2.4.6 Leaks detection

If the proponent is conducting leak surveys according to Section 9.1.4, the measuring device used for leak detection must:

• Meet the specification set out in Section 6 of Method 21^{Footnote 13} of the Environmental Protection Agency of the United States (EPA); and
• In the case of an optical gas-imaging measuring device, the device must be capable of imaging CH₄ at the leak definition concentration specified in Section 9.1.4, and be operated in accordance with the requirements of Section 8.3 of the EPA Method 21.

9.3 Measurement method and frequency

Table 5 identifies the parameters in the quantification methodology that must be measured and provides details regarding measurement method and frequency.

Table 5:Measurement method and frequency for measured parameters

Parameter	Description	Units	Measurement method and frequency	Equations
QM	Quantity of manure treated by the project MTS	t	Measured by volume or weight at least once every 15 minutes and summed for each calendar year covered by the reporting period. Or if the manure is transported by truck to the MTS site: Each truck load.	Equation 2, Equation 5
VSSource	VS measured from the source manure before mixing with any other organic material	kg VS / t manure	Measured monthly at a minimum and upon change in manure source	Equation 2
MCF	Methane conversion factor	-	Calculated based on monthly air temperature every calendar year, as per Section 9.1.3	Equation 2, Equation 4
QLS	Quantity of liquid sludge sent to storage	t	Measured continuously with volume or weight recorded at least once every 15 minutes and summed for each calendar year covered by the reporting period. Or if the sludge is transported by truck to the storage site: Each truck load.	Equation 4
QSS	Quantity of solid sludge sent to storage	t	Measured continuously with volume or weight recorded at least once every 15 minutes and summed for each calendar year covered by the reporting period. Or if the sludge is transported by truck to the storage site: Each truck load.	Equation 6, Equation 7
VSSludge	VS measured from liquid sludge stored anaerobically	kg VS/t manure	Minimum monthly and upon change of 5% or more in manure composition (based on livestock type in Table A2 in Schedule A) or change in source of other organics.	Equation 4
VSLS,pre	VS measured from the liquid sludge pre mechanical MTS	kg VS/t manure	Minimum monthly and upon change of 5% or more in manure composition (based on livestock type in Table A2 in Schedule A) or change in source of other organics.	Equation 8
FFi	Volume of fossil fuel, i, consumed by mobile and/or stationary equipment for the transport of manure and sludge, and the operation of the MTS during a calendar year covered by the reporting period	m3	Calculated from fossil fuel purchase records and/or equipment specifications and summed for each calendar year covered by the reporting period.	Equation 9
EL	Grid electricity consumed by the MTS during a calendar year covered by the reporting period	MWh	Measured using meter and summed for each calendar year covered by the reporting period. or Calculated from electricity purchasing records and/or equipment specifications and summed for each calendar year covered by the reporting period.	Equation 10
FFsupp,i	Volume of supplemental fossil fuel, i, consumed by a flare during a calendar year covered by the reporting period	m3	Calculated from fossil fuel purchasing records and/or equipment specifications and summed for each calendar year covered by the reporting period.	Equation 11
BGt	Corrected volume of biogas delivered to all eligible destruction devices during a during measurement period, t	m3 biogas	Measured continuously with volume recorded every measurement period. The measurement period can be a maximum of 1h. or Quantified as per Equation 15 if flow meter does not automatically correct volume.	Equation 14
MCt	Average CH4 content of the biogas during measurement period, t	m3 CH4 /m3 biogas	Measured continuously with CH4 content averaged over the measurement period. The measurement period can be a maximum of 1h.	Equation 14
BGUC,t	Uncorrected volume of biogas delivered to eligible destruction device, i, during measurement period, t	m3 biogas	Measured continuously with volume recorded every measurement period. The measurement period can be a maximum of 1h.	Equation 15
Tt	Measured temperature of the biogas for the measurement period, t	K	Measured continuously with value recorded every measurement period if flow meter does not automatically correct volume. The measurement period can be a maximum of 1h but must be the same frequency as for BGUC.	Equation 15
Pt	Measured pressure of the biogas for the measurement period, t	kPa	Measured continuously with value recorded every measurement period if flow meter does not automatically correct volume. The measurement period can be a maximum of 15 minutes but must be the same frequency as for BGUC.	Equation 15

9.4 Quality assurance and quality control

The proponent must have documented quality assurance and quality control (QA/QC) procedures and must implement them to ensure that all measurements and calculations are made in accordance with this protocol and can be verified.

All measuring devices listed in Section 9.2 must be:

• Checked for accuracy by following manufacturer specifications at least once each calendar year, with the last occurring no more than 2 months before or after the end of the reporting period; and
• Calibrated by the manufacturer or by a third party certified for that purpose and following manufacturer specifications, in accordance with the manufacturer specified frequency or every 5 years, whichever is more frequent, except for measuring devices manufactured with no possibility of calibration.

The measurement accuracy of all measuring devices must show that the measuring device provides a reading that is within a ± 5% accuracy range. When the accuracy of the measuring device deviates from the ± 5% range, the appropriate corrective actions must be taken, in accordance with the manufacturer specifications. 

After the corrective actions, the measuring device must be rechecked for accuracy. If the accuracy of the measuring device is still not within the ± 5% range, the measuring device must be calibrated by the manufacturer or by a third party certified for that purpose and following manufacturer specifications, no more than two months after the end of the reporting period. If the measuring device was manufactured with no possibility of calibration, it must be replaced no more than two months after the end of the reporting period.

When the measurement accuracy of a measuring device, except for leak detection measuring device, indicates a reading outside of a ± 5% accuracy range, the following rules must be applied for the entire period from the last time the measuring device showed a reading within ± 5% accuracy until the measuring device shows a return to ± 5% accuracy:

• When the inaccuracy of the measuring device indicates an under-reporting, the measured values must be used without correction;
• When the inaccuracy of the measuring device indicates an over-reporting, the measured values must be corrected by the percentage that the accuracy of the measuring device deviated from the ± 5% range.

When the measurement accuracy of a leak detection measuring device indicates a reading outside of a ± 5% accuracy range, any leak survey conducted during the period from the last time the measuring device showed a reading within ± 5% accuracy until the measuring device shows a return to ± 5% accuracy, is considered as not valid. In such case, and as per Table 5, the proponent must use a leak rate (parameter LR) of 0.05.

9.5 Missing data

If a measuring device fails to produce data as required in Section 9.1, 9.2, and 9.3, missing data may be substituted using the requirements in Section 9.5. If missing data cannot be substituted as per the applicable requirements, GHG emission reductions generated in the period during which data is missing are not eligible for credit issuance.

In the event that periods of missing data occur more than once during the reporting period, data may be substituted for:

• No more than 5% of the GHG emission reductions for the reporting period, if the GHG emission reductions are less than 100,000 tonnes of CO₂e; or
• No more than 2% of the GHG emission reductions for the reporting period, if the GHG emission reductions are equal to or greater than 100,000 tonnes of CO₂e.

9.5.1 Missing data from a biogas measuring device

Missing data from a biogas measuring device (i.e. flow meter or methane analyzer) must not be substituted unless the operational status of eligible destruction devices can be demonstrated in accordance with the requirements in Section 9.5 during the period of missing data. Missing data from a flow meter or methane analyzer may only be substituted in accordance with the following rules:

• Biogas volume data may be substituted when CH₄ content data is not missing and the methane analyzer is demonstrated to be functioning properly; or
• CH₄ content data may be substituted when biogas volume data is not missing and the flow meter is demonstrated to be functioning properly.

For a project with biogas volume or CH₄ content data missing for a period of up to seven consecutive days, the appropriate substitution method from Table 6 must be employed to substitute the data.

Table 6: Missing data substitution methods for biogas measuring devices

Missing data period	Substitution method
Less than 6 consecutive hours	Use the average of the 4 hours immediately prior to and after the missing data period.
6 to less than 24 consecutive hours	Use the 95% upper or lower confidence limit of the 72 hours prior to or after the missing data period, whichever results in greater conservativeness.
1 to 7 consecutive days	Use the 90% upper or lower confidence limit of the 72 hours prior to or after the missing data period, whichever results in greater conservativeness.
More than 7 consecutive days	No data may be substituted after the 7th consecutive day, and no GHG emission reductions may be quantified.

9.5.2 Missing data from VS testing

The proponent may substitute missing data from VS monthly testing in manure or sludge only if the following two conditions are met:

• No change in the following attributes occurred since the previous test for which VS data are available:
  • Source of manure, if missing manure VS data, or
  • Source of any feedstock and feedstock composition by more than 5%, if missing sludge VS data; and
• VS data from the month prior to the month of the missing VS data is available.

If the conditions for substitution listed above are met, the proponent may use the appropriate VS value (i.e. manure or sludge) from the month prior to the month of the missing VS data to use in Equation 2 (VS_Source,i,m), if missing data from manure VS, or in Equation 4 (VS_Sludge,m), if missing data from sludge VS.

If the conditions for substitution listed above are not met, GHG emission reductions generated during the month of the missing data are not eligible for credit issuance. The proponent must set the value of VS_Source,i,m in Equation 2 and the value of VS_Sludge,m in Equation 4 to zero.

9.5.3 Missing data from pH measurement for chemical MTS

For a project including a chemical MTS with pH data missing for a period of up to seven consecutive days, the proponent must use the 90% upper or lower confidence limit of the 72 hours prior to or after the missing data period, whichever results in greater conservativeness.

No data may be substituted after the 7th consecutive day, and the chemical MTS is deemed non-operation as per Section 9.6.1.

9.6 Operational status of MTS

9.6.1 Operational status of a chemical MTS

The proponent must monitor the operational status of a chemical MTS by a pH measuring device as per Section 9.2.2.

The chemical MTS is considered operational if the daily average pH is 5.5 or less, and if it is above 5.5 for 7 consecutive days or less. The chemical MTS is considered as not operational if the daily average pH remains above 5.5 for more than 7 consecutive days.

If an interruption in the operational status occurs in the period of May to October and lasts for more than one month, the chemical MTS is considered operational again once the two following conditions are met:

• The manure or sludge storage has been emptied; and
• The average daily pH after emptying is at or below 5.5.

For all other interruptions in operational status, i.e. interruptions lasting less than a month in the period of May to October, or interruptions of any duration occurring in the period off November to April, the chemical MTS is considered operational again once the two following conditions are met:

• Additional sulfuric acid has been added to the anaerobic storage to correct the pH; and
• The average daily pH returns to 5.5 or less.

If during a period of time a chemical MTS is considered as not operational, its operational status cannot be confirmed or the system is not functioning, GHG emission reductions generated during this period are not eligible for credit issuance.

9.6.2 Operational status of AD MTS eligible destruction devices

For an AD MTS, the proponent must monitor the operational status of all eligible destruction devices by using, for each destruction device, a monitoring instrument that records the operational status at least once per hour.

For a flare (open or enclosed), the operational status must be determined based on data from a thermocouple. For the flare to be considered operational, the thermocouple must indicate that the flare temperature meets or exceeds 260˚C (the minimum combustion temperature for CH₄).

For all other destruction devices listed in Table 1, a destruction device monitoring instrument must monitor and record an indicator of operational status appropriate for the destruction device such as energy output.

Requirements for the operational status of destruction devices apply to all eligible destruction devices located within the project site, including those located at an adjacent facility owned by an end user.

In cases where biogas is destroyed in an eligible destruction device located at an adjacent facility and owned by an end user, the proponent must obtain the monitoring data demonstrating the operational status of the eligible destruction, otherwise no GHG emission reductions can be included in the quantification.

If during a period of time an eligible destruction device is considered as not operational, its operational status cannot be confirmed or the device is not functioning, any GHG emission reductions generated during this period are not eligible for credit issuance.

10.0 Records

10.1 General records

In addition to the record keeping requirements specified in the Regulations, the proponent must retain records that support the implementation of a project, including invoices, contracts, metered results, calculations, databases, photographs, equipment maintenance and calibration records at the location and for the period of time specified in the Regulations. These records apply to any eligible manure treatment systems, measuring devices or meters located at the project site, including adjacent facilities, if applicable.

10.1.1 Project site

The proponent must keep a record of the information about the project site, including:

• For a livestock operation existing for more than two years prior to the project start date:
  • Documents showing the type of manure storage and its depth that apply to the two years prior to the project start date, including but not limited to engineering design documents or nutrient management plans,
  • Photographs or operational logs showing the use of the manure storage during the two years prior to the project start date,
  • Documents showing that manure storage was not fitted with equipment to recover and destroy manure biogas, and
  • Documents showing that manure did not go through a chemical MTS before entering anaerobic storage;
• Details about the project MTS, including:
  • Manufacturer specifications for the operation and maintenance of the project MTS, including the maximum quantity of feedstock that can be treated by the MTS,
  • Documentation describing the location and arrangement of all the components of the MTS. The documentation must show the location relative to all other MTS located within the project site,
  • Documentation related to authorizations for the project MTS, including provincial permits and environmental impact assessments if applicable, and
  • Data indicating the operational status of the MTS along with evidence that the equipment is operating according to the manufacturer specifications;
• Average monthly air temperature sourced from Government of Canada’s historical weather data using information from the nearest weather station^{Footnote 14};
• Documentation describing the type of storage of all sludge types exiting the MTS;
• Documentation showing the date the MTS was first commissioned;
• Documentation related to all operating permits for the MTS site, including their effective dates and any details related to manure treatment; and
• Documentation related to project design considerations for the installation and safe operation of the MTS.

10.1.2 Eligible manure

The proponent must keep a record of the information about the eligible manure treated by the project MTS, including:

• Records showing the category of animal producing manure treated by the MTS, as per the categories listed in Table A2;
• Documents, such as operating logbooks, showing that no other organic materials were mixed with manure except for animal bedding;
• Standard operating procedures for VS sampling in manure and sampling logbooks;
• Laboratory reports for VS in manure; and
• Documentation of any provincial or territorial legislation applicable to the project site related to manure management that may impact manure eligibility or baseline quantification, such as but not limited to manure handling plans or nutrient management plans.

10.1.3 Measuring devices and equipment

The proponent must keep a record of the information about the measuring devices and equipment, including:

• Documentation describing the installation and operation of the device:
  • Device type, model number and/or serial number for each measuring device applicable to the project MTS as per Section 9.2,
  • Manufacturer specifications for the maintenance and calibration of each measuring device included in the project,
  • Documentation describing the location and arrangement of all measuring devices included in the project, and
  • Documentation indicating the proper functioning of each measuring device included in the project in accordance with the manufacturer specifications;
• The maintenance records for each measuring device and equipment, including records of accuracy checks;
• Documentation describing the corrective measures applied if a measuring device or meter fails to meet the requirements for measurement accuracy;
• The calibration certificates and/or other records from either the manufacturer or a third-party certified for that purpose for each measuring device or meter which indicate calibration date, time, and results; and
• All information and data used to support the quantification of the GHG emission reductions, including:
  • All manure mass or volume data,
  • Manure density data if quantity is measured by volume,
  • Acidified liquid sludge pH data, if applicable,
  • All biogas volume data, corrected to the reference temperature and pressure conditions as set out in Table A1, either automatically or using Equation 15, if applicable,
  • All biogas CH₄ content data, if applicable,
  • All uncorrected biogas volume data if a flow meter does not automatically correct volume, and
  • Measured temperature and pressure data for the biogas if a flow meter does not automatically correct volume.

10.1.4 Energy usage

The proponent must keep a record of the information about fossil fuel and/or electricity consumed by the MTS, including:

• For meters under control of the proponent:
  • Documentation describing all fossil fuel and electricity meters used, including the meter model number or serial number,
  • Manufacturer specifications for the maintenance and calibration of each meter,
  • Documentation indicating the proper functioning of each meter in accordance with the manufacturer specifications, and
  • Documentation and certificates demonstrating that the checks and calibration of meters were conducted in accordance with the manufacturer specifications and Section 9.4;
• For meters that are not under control of the proponent:
  • Documentation describing all fossil fuel and/or electricity meters used and, if available, documentation demonstrating maintenance and calibration have been conducted in accordance with manufacturer specifications;
• Documentation describing the location and arrangement of all fossil fuel and/or electricity meters;
• Metered quantities or purchase records that indicate the quantity and types of fossil fuel and/or electricity consumed by the project MTS; and
• Metered quantities or purchase records that indicate the quantity and types of fossil fuel and/or electricity consumed by vehicles for the transportation of manure, sludge, and/or sulfuric acid, if applicable.

10.2 Records specific to a chemical MTS

The proponent must keep a record of the information about acidified liquid sludge, including:

• Records that demonstrate the quantity of sulfuric acid used to treat manure such as purchase records or measurement records;
• Records showing the distance between the chemicals retail point to the manure treatment site and the category of vehicle used to transport chemicals used in the project MTS;
• Acidified liquid sludge pH data; and
• The location of all land receiving acidified liquid sludge during the reporting period

10.3 Records specific to a mechanical MTS

The proponent must keep a record of the information about the mechanical MTS, including:

• All information and data used to support the quantification of the GHG emission reductions, including:
  • All solid or liquid sludge mass or volume data,
  • Sludge density data, if quantity is measured by volume, and
  • VS data from laboratory reports for liquid sludge stored anaerobically; and
• Standard operating procedures for VS sampling in liquid sludge and sampling logbooks.

10.4 Records specific to an AD MTS

The proponent must keep a record of the information about the AD MTS, including:

• All information and data used to support the quantification of the GHG emission reductions, including:
  • All biogas volume data, corrected to the reference temperature and pressure conditions as set out in Table A1, either automatically or using Equation 15,
  • All biogas CH₄ content data, if applicable,
  • All uncorrected biogas volume data if a flow meter does not automatically correct volume,
  • Measured temperature and pressure data for the biogas if a flow meter does not automatically correct volume,
  • All solid or liquid sludge mass or volume data,
  • Sludge density data if quantity is measured by volume, and
  • VS data from laboratory reports for liquid sludge stored anaerobically;
• Standard operating procedures for VS sampling in liquid sludge and sampling logbooks;
• A copy of any agreements between the proponent and an end user of the biogas stating that no offset credits issued for the GHG emission reductions generated by the project will be claimed by the end user, and no credits will be attributed under another GHG reduction mechanism to the end user for the GHG emission reductions generated by the project;

• A copy of any agreements/contracts in place for the sale of biogas to be destroyed at the project site or adjacent destruction facility, directly injected into a natural gas network, and/or compressed or liquefied prior to transport and injection into a natural gas network, if applicable;
• Documentation demonstrating the sale of any biogas to be destroyed at the project site or adjacent destruction facility, directly injected into a natural gas network, and/or compressed or liquefied prior to transport and injection into a natural gas network, including the actual quantities sold during the reporting period, if applicable;
• If applicable, the testing data and documentation pertaining to the site-specific leaks rate; and
• Details about eligible destruction devices, including:
  • Documentation describing eligible destruction devices included in the project,
  • Manufacturer specifications for the operation and maintenance of eligible destruction devices included in the project,
  • If applicable, the testing data and documentation pertaining to the device-specific destruction efficiency for eligible destruction devices included in the project,
  • Documentation describing the location and arrangement of eligible destruction devices, including if an eligible destruction device is located at an adjacent destruction facility, and
  • Data indicating the operational status of eligible destruction devices along with evidence that the equipment is operating according to the manufacturer specifications.

11.0 Reporting

In addition to the reporting requirements specified in the Regulations, the proponent must include the following in project reports.

In the initial project report, the proponent must include:

• For a livestock operation existing for more than two years prior to the project start date, information on the anaerobic manure storage used at livestock operation during the two years prior to the project start date, including the type and depth of the storage structure, and whether the manure went through mechanical or chemical MTS before entering the anaerobic storage;
• A clear description of the eligible project activities undertaken for each full or partial calendar year of a reporting period;
• Type of livestock at the livestock operation as per categories in Table A2; and
• The type(s) of MTS used and, if applicable, a description of their configuration and arrangement in the project (i.e., describing the flow of raw manure and intermediary sludges between MTS)

In any project report, the proponent must include:

• The collected data as per the method and frequency prescribed for applicable parameters in Table 5;
• For AD MTS:
  • The maximum capacity of AD MTS,
  • Data indicating the operational status of the MTS and destruction device as per Section 9.6.2, and
  • The data and information used for determination of leak rate as per Sections 9.1.4 and 9.2.4.6;
• For mechanical MTS:
  • Type of mechanical MTS, and
  • Maximum capacity and separation efficiency level;
• For chemical MTS:
  • Data indicating the operational status of the MTS as per Sections 9.2.2 and 9.6.1;
• The quantified GHG emissions for each SSR included in the baseline and project scenarios in tCO₂e for each full or partial calendar year covered by the reporting period; and
• A crop nutrient plan completed by a Professional Agrologist (P.Ag.) or Certified Crop Advisor (CCA) for all lands receiving acidified liquid sludge during the reporting period, showing that:
  • The lower pH of acidified liquid sludge has been accounted for and addressed as per Section 6.3.2, and
  • The increased nitrogen content of acidified liquid sludge has been accounted for and addressed as per Section 6.3.2.

Schedule A

Table A1: Reference condition values

Parameter	Description	Value	Units	Reference source
Tref	Reference temperature of the biogas	298.15	K	Physical constant
Pref	Reference pressure of the biogas	101.325	kPa	Physical constant
ρCH4	Reference density of CH4 (at Tref and Pref conditions)	0.656	kg/m3	Physical constant

Table A2: Maximum CH₄ producing potential (B₀) by livestock type^{Footnote 15}

Livestock type (T)	B0 (m3 CH4 / kg VS)
Dairy cattle	0.24
Beef cattle	0.19
Swine	0.48
Hens	0.39
Broilers	0.36
Turkeys	0.36
Sheep	0.19
Goats	0.18
Horses	0.30

Table A3: Storage emission factors by storage type for MTS sludge types

Sludge	Storage type (S)	CH4 Emission Factor (EFSludge,CH4)	N2O Emission Factor (EFSludge,N2O)
Liquid	Anaerobic storage, non acidified	1	0
Liquid	Anaerobic storage, acidified	0.05	0
Solid	Static piles or otherFootnote 16 composting	3.54 kg CH4/t sludge, wet weight	0.18 kg N2O/t sludge, wet weight
Solid	Deep beddingFootnote 17	0	0