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British Columbia Greenhouse Gas Offset Protocol

VENTED EMISSIONS

REDUCTIONSPublic Consultation Draft

_____________________________

Date

____________________________________________

Director

Greenhouse Gas Industrial Reporting and Control Act

Version: 1.02018

(THIS PAGE LEFT INTENTIONALLY BLANK)

B.C. Vented Emissions Reductions GHG Offset Protocol |

TABLE OF CONTENTS1.0 Guidance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

2.0 Definitions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5

3.0 Applicability. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7

3.1 Criteria . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7

3.2 Project Start Date . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

3.3 Project Crediting Period. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

3.4 Project Report Period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

3.5 Materiality . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

4.0 Project Boundary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9

4.1 Description of the Project . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9

4.2 Identification of the Project Location . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9

5.0 Establishment of Baseline Scenario . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

5.1 Project Specific Approach . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

6.0 Categorization and Description of Selected Project and Baseline SSRs . . . . . . . . . . . . . . . . . . . . . . 11

7.0 Project Justification . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13

8.0 Quantification of Emissions Reduction and Removal Enhancements. . . . . . . . . . . . . . . . . . . . . . . . 14

8.1 Quantification of Baseline Emissions and Removals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158.1.1 B1 Baseline Vented Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158.1.2 B2 Baseline Fuel Consumption . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15

8.2 Project Emissions and Removals. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158.2.1 P1 Project Vented Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158.2.2 P2 Project Fuel Consumption . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 168.2.3 P3 Vent Gas Capture . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 168.2.4 P4 Process Control Electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 178.2.5 P5 Air Compression . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18

8.3 Leakage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19

8.4 Project Reductions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19

9.0 Project Reduction Estimates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20

10.0 Data Collection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21


1.0 GUIDANCE This Protocol has the effect of a regulation and establishes mandatory requirements for the carrying out of Emissions Reduction Projects.

The Project Proponent is responsible to ensure the Validation Body selected for a Project using this Protocol is accredited by the Standards Council of Canada to Technical Sector B: GHG emission reductions from industrial processes (non-combustion, chemical reaction, chemical fugitive emissions, flare & venting from oil, and other) or by the American National Standards Institute to Sector Group 2: GHG emission reductions from industrial processes (non-combustion, chemical reaction, fugitive, and other).

For a Project that involves Vented Gas Reductions from Pneumatic Devices in upstream oil and gas operations, the Project Plan may be prepared in accordance with this Protocol.

The Project Proponent is responsible to provide justification where any assumptions or estimates are used in the Project Plan.

The Project Proponent is responsible to ensure the requirements of the Protocol, the Act and Regulations are met, and required forms are complete.

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2.0 DEFINITIONS In the Protocol, the capitalization of terms where the capitalization is not solely performing a grammatical function indicates a defined term in the Act, Regulation or this section.

“Affected source, Sink or Reservoir” means a greenhouse gas (GHG) source, Sink or Reservoir that is influenced by the Primary Activity through changes in market demand or supply of associated products or service or through physical displacement.

“Controlled source, Sink, or Reservoir” means greenhouse gas (GHG) source, Sink or Reservoir whose operation is under the direction and influence of the Project Proponent through financial, policy, management or other instruments.

“Dynamic Vent Rate” means the rate at which a pneumatic device intermittently vents based on field operations and control processes. Supply pressure, quality of gas and age of device can all impact the dynamic vent rate.

“Energy Service Process” means a process or processes carried out that:

(a) generates electricity or steam;

(b) heats, cools or compresses solid, liquid or gas; or,

(c) provides motive force to a mechanical process.

“Fuel” includes electricity and material that is combusted or transformed to generate usable energy or do work.

“Fuel Gas” means portions of the sales gas used for site operations including fuel for engines and pressure supply for pneumatic devices.

“Functional Equivalence” refers to the project and the baseline providing the same function and quality of products or services. For the purpose of this protocol, functional equivalence is defined as the same volume of oil or gas throughput under the same conditions.

“High Venting Pneumatic Device” means a pneumatic device commonly used in the oil and gas sector such as a pneumatic controller or pump with a manufacturer-specified static GHG vent rate of lower than 0.17 standard cubic meters per hour of natural gas.

“Initial Testing Period” means the period of time between when the system is installed and when the system becomes operational.

“Instrument Air” means ambient air that is pressurized to supply a pneumatic device as an alternative to natural gas while providing the necessary level of control required for its intended use.

“Integrated Grid” means an electrical distribution system that is connected to a transmission system operated by BC Hydro or FortisBC.

“Isolated Grid” means an electrical distribution system that is not connected to the Integrated Grid.

“Leak” means unintended emissions from sources including worn seals, gaskets, and diaphragms; nozzle corrosion or wear from poor quality gas leading to increased flow; and loose control tube fitting in a pneumatic device.

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“Low Venting Pneumatic Device” a pneumatic device commonly used in the oil and gas sector such as a pneumatic controller or pump with a manufacturer-specified static GHG vent rate of lower than 0.17 standard cubic meters per hour of natural gas.

“Monitoring” means the continuous or periodic assessment and documentation of GHG emissions and removals or other GHG-related data.

“Non-venting Pneumatic Device” means a control or pumping device that performs its functions with zero GHG emissions, for example a pneumatic device converted to use renewable energy.

“Operation” means a facility(s), location(s) or process(es) where the Primary Activity of the Project Scenario occurs or Primary Activity of the Baseline Scenario would occur.

“Pneumatic Controller” means a type of automated control device that regulates the supply of pressure to an actuator or control loop, which opens, closes and/or positions a valve to regulate the flow of oil, gas or any other production/process fluid.

“Pneumatic Device” for the purpose of this protocol means pneumatic controllers and pneumatic pumps, which are control and pumping devices heavily used in the upstream oil and gas industry.

“Pneumatic Pump” means a type of device that uses gas pressure to drive a fluid by raising or reducing the pressure of the fluid. Pneumatic pumps are generally used at oil and gas production sites to inject various chemicals into pipelines, vessels, and wells to prevent corrosion and freezing of entrained fluids.

“Primary Activity” means the main activity or set of activities in the Project Scenario that result in the majority of the Emissions Reduction from the Functionally Equivalent Baseline Scenario.

“Project Scenario” means the activities that have an effect on GHG emissions and constitute the estimation of the Project Emissions.

“Project Specific” means an approach to establish the Baseline Scenario that is specific to the Project.

“Regulation” means the Greenhouse Gas Emission Control Regulation.

“Replacement” means the complete swap from one pneumatic device to an alternative.

“Static Vent Rate” means the rate at which a device continuously vents air or natural gas based on manufacturer specification at a steady-state of operation.

“Vented Gas” means CO2 and CH4 released into the atmosphere in a controlled manner over the course of oil and gas production operations.

“Vent Rate” means the rate at which a device vents air or natural gas intermittently due to design requirements, and is the sum of both static and dynamic rates.

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3.0 APPLICABILITY3.1 Criteria

1. The Project must involve the replacement of a Pneumatic Device and/or modifications to equipment at an existing site.

2. The Project Reduction must not result from:

a) the reduction of propane venting and/or conversion from propane to methane; or,

b) a project that is a component of an agreement under the British Columbia Clean Infrastructure Royalty Credit Program.

3. The Primary Activity of the Project Scenario must be an activity:

a) that involves the adoption of one or more of the project types shown in Table 1 where, at minimum,

i. Low Venting and Non-venting Pneumatic Devices are effective replacements based on manufacturer specifications;

ii. Vent Gas capture systems are installed in a manner which allows relief of vent backpressure to maintain functionality of Pneumatic Devices; and

iii. Compressed air systems match or exceed the supply pressure at design volume requirements to meet pneumatic demand.

This protocol is not intended to apply to mobile sources of greenhouse gas emissions.

Table 1: Project Type Applicability

Project Type Applicability Criteria

High to Low Venting Pneumatic Controller conversion

Project must involve removal of a functioning high venting controller and replacement with a low venting controller.

Instrument gas to Instrument Air conversion for Pneumatic Device operation.

Project must involve disconnection of an instrument gas supply system from an existing natural gas supply and connection to a compressed air supply system, for operation of a Pneumatic Device.

Vent gas capture Project must involve connecting an existing High Venting Pneumatic Device to a vent gas capture system.

Pneumatic Device electrification Project must involve removal of a pneumatic Device and replacement with an electrically powered device.

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3.2 Project Start DateThe Start Date is asserted by the Project Proponent in accordance with the Regulation (section 14 (3) (n) (i)) and must be a date on or before the completion of the Initial Testing Period. An Initial Testing Period must not exceed three months from the day the Primary Activity of the Project Scenario started performing its intended function.

3.3 Project Crediting PeriodThe Crediting Period begins on the Project Start Date and ends on December 31st, 2022 or when federal, provincial or municipal law becomes required for activities under this Protocol; whichever occurs first. The Project Proponent must provide justification for the length of the Crediting Period based on the analysis used to establish Baseline and Project Scenarios.

3.4 Project Report Period The first Project Report Period begins on the Project Start Date. The Project Report Period must be a 12-consecutive-month period (e.g. October 16, 2018 – Oct 15, 2019, October 16, 2019 – October 15, 2020, etc.) except for the first and last Project Report Periods. The first Project Report Period may be from six to eighteen months in length if the purpose is to align the Project Report Periods with other business requirements (e.g. October 16, 2018 – December 31, 2019 for alignment with a calendar year). If the first Project Report Period is not twelve consecutive months, then the last Project Report Period must be less than twelve consecutive months so that the total length of all Project Report Periods matches the length of the Crediting Period.

3.5 Materiality For the purpose this Protocol, any errors, omissions or misrepresentations are considered material as per (sections 15 (3) (c) and 21 (4) (c)) of the Regulation if the individual or aggregate effects may result in an overestimation of the Project Reduction of more than 5%.

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4.0 PROJECT BOUNDARY4.1 Description of the ProjectThe Project Proponent must provide a detailed technical description of the Project, technologies and measures employed, and how a Project Reduction will be achieved.

The description must include a list of facilities, systems and equipment in operation in the Baseline Scenario prior to the implementation of the Project and over the life of the Project. For each facility, system and piece of equipment, the Project Proponent must provide:

• the age and average life of the equipment based on manufacturer’s specifications and industry standards;

• existing and forecasted installed capacities, load factors and efficiencies;

• a diagram of the Energy Services Process equipment; and,

• an explanation of how the Project is Functionally Equivalent to the Baseline Scenario. The explanation must include the types and levels of goods and services provided by the Energy Service Process and any relation to equipment and systems outside the Project boundary.

4.2 Identification of the Project Location Project Plans must include latitude and longitude for the location where the Primary Activity of the Project Scenario will be carried out and any other information allowing for the unique identification of the Primary Activity of the Project Scenario. Street address and postal code must be provided, if available.

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5.0 ESTABLISHMENT OF BASELINE SCENARIO

The Baseline Scenario is determined using a project specific assessment of Baseline Scenario candidates. A performance standard approach may not be used.

5.1 Project Specific ApproachThe Project Proponent must select the Baseline Scenario after:

1. listing Baseline Scenario candidates,

2. identifying obstacles for each candidate, and

3. conducting a comparative assessment of obstacles for each candidate.

The Project Plan must list and describe all reasonable Baseline Scenario candidates which include existing and alternative types of activities, technologies and Fuels. One of the Baseline Scenario candidates must be the continuation of historic practices.

The Project Plan must identify potential obstacles associated with implementing each of the list-ed Baseline Scenario candidates. Obstacles to be identified, if they exist, must include, but are not limited to:

• access to credit or capital, and other factors related to capital cost,

• operating costs,

• availability and/or cost of technological expertise,

• availability of infrastructure related to types of Fuel available at the site, transmission and distribution equipment, and any necessary structures,

• institutional resistance,

• challenges in procurement of, or costs of obtaining, a reliable supply of alternative Fuel types,

• social acceptance and,

• legal requirements.

The Project Proponent must estimate the relative magnitude and risk of each obstacle for each Baseline Scenario candidate identified. The magnitude and risk of an obstacle must be quantified and monetized as much as practicable. When characterizing an obstacle qualitatively the magnitude and risk must include a detailed explanation and justification.

The Project Proponent must substantiate their assessment and explain why the selected Baseline Scenario candidate is the reasonable choice for the Baseline Scenario.

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6.0 CATEGORIZATION AND DESCRIPTION OF SELECTED PROJECT AND BASELINE SSRs

The Project Plan must include sources listed in Figure 1 and Table 2. There are no Reservoirs or Sinks associated with this Protocol. sources, sinks and reservoirs (SSRs) include GHGs: CO2, CH4 and N2O.

Figure 1 – Selected sources, sinks and reservoirs (SSRs)

Baseline Sources, Sinks and Reservoirs in scope

Project sources, sinks and reservoirs in scope

Vent Gas Capture

Process Control

Electricity

Air Compression

Fuel Gas captured for

use or flaring

Electricity used to run process

control instruments

Electricity used run air compression

devices and air management

systems

Grid Supplied Self-generated

Grid Supplied Self-generated

Vented Gas from Pneumatic

Devices

Combustion of Fuel on-site

Vented Gas

Fuel Consumption

P3 P4 P5

B1 B2

P1 P2

Vented Gas from Pneumatic

Devices

Combustion of Fuel on-site

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Table 2: Selected SSRs

SSR DescriptionB1 (Controlled) P1 (Controlled)

Primary Activity: Vented Gas

GHG emissions associated with Fuel Gas or raw gas vented from Pneumatic Devices as part of regular operations. This source is the Primary Activity of the Baseline Scenario and Project Scenario.

B2 (Related) P2 (Related)

Fuel Consumption

GHG emissions from the on-site combustion of Fuels. The total volumes of Fuel for each of the sources / sinks in this project are considered in this source/sink. Types and quantities of fuels used throughout would need to be tracked.

P3 (Controlled)

Vent Gas Capture

GHG emissions associated with the capture of vent gas in the project must be tracked. This includes GHG emissions that normally would be vented from Pneumatic Devices but is captured and redirected into the pipeline or used as a fuel for onsite processes.

P4 (Controlled)

Process Control Electricity

GHG emissions associated with electricity required for operating electrified control devices or electric chemical pumps that are additional to the baseline condition. This electricity may be sourced from and Isolated or Integrated Grid. Metering of electricity may be netted in terms of the power going to and from the grid.

This source will be zero when for air or solar powered devices.P5 (Controlled)

Air Compression

GHG emissions associated with electricity used to run air compressors and air management systems that supply compressed air to pneumatic instruments.

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7.0 PROJECT JUSTIFICATION The Project Proponent must identify in the Project Plan the obstacles to the Project in the same manner as required for Baseline Scenario candidates in section 5.

The Project Proponent must assert and justify in the Project Plan that there are financial, technological or other obstacles to carrying out the Project that are overcome or partially overcome by having the Project Reductions recognized as Offset Units. The justification in the Project Plan must include:

• financial analysis including the impact of carbon finance on investment hurdle rates and decision-making,

• how the economic business case and values used in the financial analysis compare to those commonly used by the Project Proponent and industry-specific standards,

• the anticipated rate of adoption of the Primary Activity over the Crediting Period

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8.0 QUANTIFICATION OF EMISSIONS REDUCTION AND REMOVAL ENHANCEMENTS

The Project Proponent must use section 8 to quantify Baseline Emissions, Project Emissions and Project Reductions.

Each SSR in Table 2 of section 6 is calculated using quantification methods specified for each SSR.

Equation references to ‘i’ refer to a ‘SSR’ type in of the SSR column of Table 1 in section 6. Equation references to ‘j’ refer to a ‘GHG’ type in Section 6. Equation references to ‘m’ refer to a Project Report Period, ’h’ refers to a ‘Fuel type’ and ‘f’ refers to a ‘grid type.’

References to WCI refer to the most current version of the Western Climate Initiative Final Essential Requirements of Mandatory Reporting - amended for Canadian Harmonization as published on the Ministry of Environment and Climate Change Strategy’s website. For each SSR, only specific calculation methods within WCI.20 General Stationary Combustion and WCI.360 Petroleum and Natural Gas Production and Processing are permitted. In using WCI, references to quantification of annual GHG emissions are to be adapted to reflect the time period of the given Project Report Period.

If more than one option exists, the Project Proponent must select the most accurate quantification method unless the alternative method in the Protocol provides a result that is materially the same and the selection is justified.

To convert individual GHG totals into total GHG emissions in units of tonnes of CO2 equivalent (tCO2e) Equation 1 is used.

Equation 1: Conversion to tonnes of CO2e

Where:

Total GHG Emissionsi,m = Total GHG emissions in tCO2e for SSR i for Project Report Period m (tonnes of CO2e).

Ti,j,m = Total GHG emissions of GHG j for SSR i for Project Report Period m (tonnes of CO2, tonnes of CH4 or tonnes of N2O).

GWPj = 100-year global warming potential for GHG j relative to CO2.

Global warming potentials (GWP) for GHG j (CO2, CH4 or N2O) must use the latest values set out in Column 4 of the Schedule to the Carbon Neutral Government Regulation.

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8.0 QUANTIFICATION OF EMISSIONS REDUCTION AND 257

REMOVAL ENHANCEMENTS258

The Project Proponent must use section 8 to quantify Baseline Emissions, Project Emissions 259and Project Reductions. 260

261Each SSR in Table 2 of section 6 is calculated using quantification methods specified for each 262SSR. 263

264Equation references to ‘i’ refer to a ‘SSR’ type in of the SSR column of Table 1 in section 6. 265Equation references to ‘j’ refer to a ‘GHG’ type in Section 6. Equation references to ‘m’ refer to 266a Project Report Period, ’h’ refers to a ‘Fuel type’ and ‘f’ refers to a ‘grid type.’267

268References to WCI refer to the most current version of the Western Climate Initiative Final 269Essential Requirements of Mandatory Reporting - amended for Canadian Harmonization as 270published on the Ministry of Environment and Climate Change Strategy’s website. For each 271SSR, only specific calculation methods within WCI.20 General Stationary Combustion and272WCI.360 Petroleum and Natural Gas Production and Processing are permitted. In using WCI, 273references to quantification of annual GHG emissions are to be adapted to reflect the time 274period of the given Project Report Period.275

276If more than one option exists, the Project Proponent must select the most accurate 277quantification method unless the alternative method in the Protocol provides a result that is 278materially the same and the selection is justified.279

280To convert individual GHG totals into total GHG emissions in units of tonnes of CO2 equivalent 281(tCO2e) Equation 1 is used.282

283Equation 1: Conversion to tonnes of CO2e284

𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑖𝑖𝑖𝑖,𝑚𝑚𝑚𝑚 = ��𝑇𝑇𝑇𝑇𝑖𝑖𝑖𝑖,𝑗𝑗𝑗𝑗,𝑚𝑚𝑚𝑚 × 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝑗𝑗𝑗𝑗�𝑗𝑗𝑗𝑗

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286Where:287

288𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑖𝑖𝑖𝑖,𝑚𝑚𝑚𝑚 = Total GHG emissions in tCO2e for SSR i for Project Report 289

Period m (tonnes of CO2e).290𝑇𝑇𝑇𝑇𝑖𝑖𝑖𝑖,𝑗𝑗𝑗𝑗,𝑚𝑚𝑚𝑚 = Total GHG emissions of GHG j for SSR i for Project Report Period m (tonnes of 291

CO2, tonnes of CH4 or tonnes of N2O).292𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝑗𝑗𝑗𝑗 = 100-year global warming potential for GHG j relative to CO2.293

294Global warming potentials (GWP) for GHG j (CO2, CH4 or N2O) must use the latest values set 295out in Column 4 of the Schedule to the Carbon Neutral Government Regulation.296

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8.1 Quantification of Baseline Emissions and RemovalsIn the following sections, equations and parameters are provided for each relevant SSR for the Baseline Scenario.

8.1.1 B1 Baseline Vented Gas

The Baseline Vented Gas quantification methodology is used to determine the baseline emissions for High Venting to Low Venting Pneumatic Device Projects, electrification Projects and instrument gas to instrument air conversion Projects. The quantification methodology varies depending on the type of Project and the measurement samples available.

Quantification of GHG emissions must use WCI.363 (a) and WCI.363 (b) for calculation of vented GHG emissions from natural gas driven Pneumatic Devices (High Venting, Low Venting, and intermittent Low and High Venting).

Where applicable, use Equation 1 to convert CO2, CH4 and N2O emissions to total GHG emissions (tonnes of CO2e).

8.1.2 B2 Baseline Fuel Consumption

This emission source is the result of the use of non-electricity Fuel consumption throughout the Project.

Project proponent must use WCI.23 for quantification of CO2 emissions and WCI.24 for quantification of CH4 and N2O emissions.


8.2 Project Emissions and RemovalsIn the following sections, equations and parameters are provided for each relevant SSR for the Project.

8.2.1 P1 Project Vented Gas

The quantification methodology for Project Vented Gas is used to determine the Project emissions for High Venting to Low Venting Pneumatic Device Projects and electrification Projects and instrument gas to instrument air conversion Projects. The quantification methodology varies depending on the type of Project and the measurement samples available.

Quantification of GHG emissions must use WCI.363 (a) and WCI.363 (b) for calculation of Vented Gas GHG emissions from natural gas driven Pneumatic Devices (High venting, Low Venting, and intermittent Low and High Venting).


224

225 226

227

228 229 230 231

232 233 234

235 236

237

238 239

240 241

242 243

244

245

246

247 248 249 250

251 252 253

254 255


8.2.2 P2 Project Fuel Consumption

This emission source is the result of the use of non-electricity Fuel consumption throughout the Project.

Project proponent must use WCI.23 for quantification of CO2 emissions and WCI.24 for quantification of CH4 and N2O emissions.

Use Equation 1 to convert CO2, CH4 and N2O emissions to total GHG emissions (tonnes of CO2e).

Quantification of Electricity Fuel emissions is covered by Source P4 Process Control Electricity.

8.2.3 P3 Vent Gas Capture

The equation for Vent Gas Capture applies to vent gas capture projects that aim to eliminate venting and capture all gas from devices that would otherwise be vented into the atmosphere. Depending on the type of facility and the options available to gather data, there are different measurement samples to complete the equation.

Equation 2: P3 Vent Gas Capture

Where:

Captured Gas options are listed in preferential order. Where direct metering is not used, the project proponent must justify why direct measurement or average measurement samples were not feasible. Where measurement samples are used, evidence must be provided that the sample is representative of annual emissions.

Captured Gas (Direct Metering m3) = Directly measured from device meter

ΣVent Gas (m3) = Calculated using on WCI.363 (a) and (b)

Op.hours (hour) = Operating hours of device during the project period taken as cumulative total operating time of Catadyne/other space heater/combustion device where captured gas is directed

Load (%) = Fuel device load directly measured from combustion device

Fuel.Con.Rate (m3hr) = Fuel consumption rate as per manufacturer’s specification for the Catadyne/other space heater/combustion device where captured gas is directed

DE (%) = Destruction efficiency of combustion as per manufacturer’s specification

EFjh (kg/m3) = Combustion Emission Factor for GHG gas j (CO2, CH4, N2O)13 | D R A F T B . C . V e n t e d E m i s s i o n s R e d u c t i o n s P r o t o c o l

8.2.2 P2 Project Fuel Consumption342

This emission source is the result of the use of non-electricity Fuel consumption throughout the 343Project.344

345Project proponent must use WCI.23 for quantification of CO2 emissions and WCI.24 for 346quantification of CH4 and N2O emissions. 347

348Use Equation 1 to convert CO2, CH4 and N2O emissions to total GHG emissions (tonnes of CO2e).349

350Quantification of Electricity Fuel emissions is covered by Source P4 Process Control Electricity.351

352

8.2.3 P3 Vent Gas Capture 353

The equation for Vent Gas Capture applies to vent gas capture projects that aim to eliminate 354venting and capture all gas from devices that would otherwise be vented into the atmosphere. 355Depending on the type of facility and the options available to gather data, there are different 356measurement samples to complete the equation.357

358Equation 2: P3 Vent Gas Capture359

𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺 𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝑉𝑉𝑉𝑉360

=𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸

1000361

∗ �𝐷𝐷𝐷𝐷𝐸𝐸𝐸𝐸 ∗ (𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸ℎ𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶2 + 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸ℎ𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4 ∗ 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4) + 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸ℎ𝑁𝑁𝑁𝑁2𝐶𝐶𝐶𝐶 ∗ 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝑁𝑁𝑁𝑁2𝐶𝐶𝐶𝐶 + (1 − 𝐷𝐷𝐷𝐷𝐸𝐸𝐸𝐸) ∗ 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4362

∗ %𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺4 ∗ 𝜌𝜌𝜌𝜌𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4�363

364

Where: 365

𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 = �𝐷𝐷𝐷𝐷𝐸𝐸𝐸𝐸𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐷𝐷𝐷𝐷𝑇𝑇𝑇𝑇 𝑀𝑀𝑀𝑀𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑀𝑀𝑀𝑀

∑𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 𝑂𝑂𝑂𝑂𝐶𝐶𝐶𝐶. ℎ𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸 ∗ 𝐿𝐿𝐿𝐿𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶 ∗ 𝐸𝐸𝐸𝐸𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸 𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸.𝑅𝑅𝑅𝑅𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶

366

367Captured Gas options are listed in preferential order. Where direct metering is not used, the 368project proponent must justify why direct measurement or average measurement samples were 369not feasible. Where measurement samples are used, evidence must be provided that the sample 370is representative of annual emissions.371

372𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 (Direct Metering m3) = Directly measured from device meter 373∑𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 (m3) = Calculated using on WCI.363 (a) and (b)374𝑂𝑂𝑂𝑂𝐶𝐶𝐶𝐶.ℎ𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸 (hour) = Operating hours of device during the project period taken 375

as cumulative total operating time of Catadyne/other space 376heater/combustion device where captured gas is directed377

𝐿𝐿𝐿𝐿𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶 (%) = Fuel device load directly measured from combustion 378device 379

𝐸𝐸𝐸𝐸𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸.𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸.𝑅𝑅𝑅𝑅𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶 (m3hr) = Fuel consumption rate as per manufacturer’s specification 380for the Catadyne/other space heater/combustion device 381where captured gas is directed 382 13 | D R A F T B . C . V e n t e d E m i s s i o n s R e d u c t i o n s P r o t o c o l

8.2.2 P2 Project Fuel Consumption342

This emission source is the result of the use of non-electricity Fuel consumption throughout the 343Project.344

345Project proponent must use WCI.23 for quantification of CO2 emissions and WCI.24 for 346quantification of CH4 and N2O emissions. 347

348Use Equation 1 to convert CO2, CH4 and N2O emissions to total GHG emissions (tonnes of CO2e).349

350Quantification of Electricity Fuel emissions is covered by Source P4 Process Control Electricity.351

352

8.2.3 P3 Vent Gas Capture 353

The equation for Vent Gas Capture applies to vent gas capture projects that aim to eliminate 354venting and capture all gas from devices that would otherwise be vented into the atmosphere. 355Depending on the type of facility and the options available to gather data, there are different 356measurement samples to complete the equation.357

358Equation 2: P3 Vent Gas Capture359

𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺 𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝑉𝑉𝑉𝑉360

=𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸

1000361

∗ �𝐷𝐷𝐷𝐷𝐸𝐸𝐸𝐸 ∗ (𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸ℎ𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶2 + 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸ℎ𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4 ∗ 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4) + 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸ℎ𝑁𝑁𝑁𝑁2𝐶𝐶𝐶𝐶 ∗ 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝑁𝑁𝑁𝑁2𝐶𝐶𝐶𝐶 + (1 − 𝐷𝐷𝐷𝐷𝐸𝐸𝐸𝐸) ∗ 𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4362

∗ %𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺4 ∗ 𝜌𝜌𝜌𝜌𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶4�363

364

Where: 365

𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 = �𝐷𝐷𝐷𝐷𝐸𝐸𝐸𝐸𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐷𝐷𝐷𝐷𝑇𝑇𝑇𝑇 𝑀𝑀𝑀𝑀𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑀𝑀𝑀𝑀

∑𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 𝑂𝑂𝑂𝑂𝐶𝐶𝐶𝐶. ℎ𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸 ∗ 𝐿𝐿𝐿𝐿𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶 ∗ 𝐸𝐸𝐸𝐸𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸 𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸.𝑅𝑅𝑅𝑅𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶

366

367Captured Gas options are listed in preferential order. Where direct metering is not used, the 368project proponent must justify why direct measurement or average measurement samples were 369not feasible. Where measurement samples are used, evidence must be provided that the sample 370is representative of annual emissions.371

372𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 (Direct Metering m3) = Directly measured from device meter 373∑𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇 𝐺𝐺𝐺𝐺𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸 (m3) = Calculated using on WCI.363 (a) and (b)374𝑂𝑂𝑂𝑂𝐶𝐶𝐶𝐶.ℎ𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸 (hour) = Operating hours of device during the project period taken 375

as cumulative total operating time of Catadyne/other space 376heater/combustion device where captured gas is directed377

𝐿𝐿𝐿𝐿𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶 (%) = Fuel device load directly measured from combustion 378device 379

𝐸𝐸𝐸𝐸𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸.𝐶𝐶𝐶𝐶𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸.𝑅𝑅𝑅𝑅𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐶𝐶𝐶𝐶 (m3hr) = Fuel consumption rate as per manufacturer’s specification 380for the Catadyne/other space heater/combustion device 381where captured gas is directed 382

256

257 258

259 260

261

262

263

264 265 266 267

268 269

270 271

272

273

274

275 276 277

278 279 280 281

282

283

284 285 286

287

288 289

290

291


GWPj = Global warming potentials for GHG j (CH4, N2O) must use the latest values from the Schedule to the Carbon Neutral Government Regulation according to 100-year reference.

%CH4 = Methane composition in Vented Gas. Direct measurement (Vented Gas composition should remain relatively stable during steady-state operation)

ρCH4 (kg/m3) = Methane density. Estimated as a reference value corresponding to conditions

at which volumes are reported. If this value is used all values must be adjusted for standard temperature and pressure (STP).

8.2.4 P4 Process Control Electricity

The Process Control Electricity equation applies to projects where a high venting device is replaced with an electrification device. The quantification applies to the electricity used to power the device and the emissions associated with the power source.

Equation 3 must be used to calculate GHG emissions associated with the electricity supplied by an Integrated Grid or Isolated Grid.

Equation 3: P4 Process Control Electricity

EmissionsElectric Process Control = ElectricityProcess Control * EFElec Supply

Where,

ElectricityProcess Control = Total quantity of electricity consumed by electric control devices replacing Pneumatic Devices for the project report period (MWh). It can be estimated or measured.

EFElec Supply = Emission factor for electricity supplied by grid (integrated or isolated) for Project Report Period (tCO2e / MWh).

EFElec Supply - Integrated Grid

For electricity supplied by an Integrated Grid, the Project Proponent must use the appropriate emission intensity factor for the Project Report Period published on the B.C. Ministry of Environment and Climate Change Strategy’s website published in accordance with Schedule E of the Greenhouse Gas Emission Reporting Regulation.

EFElec Supply - Isolated Grid

For electricity supplied by an Isolated Grid, the Project Proponent must calculate the appropriate emission factor for each technology / method of Energy Service Process using Equation 3.1.

292 293 294

295 296

297 298 299

300

301 302 303

304 305

306

307

308

309 310 311

312 313

314

315 316 317 318

319

320 321


Equation 3.1: Emission Factor Electricity Supplied by an Isolated Grid

Where:

EmissionsElect Generation = GHG emissions associated with the generation of electricity in an isolated grid for the project report period. WCI.23 must be used for quantification of CO2 emissions and WCI.24 for quantification of CH4 and N2O emissions. Use Equation 1 to convert CO2, CH4 and N2O emissions to total GHG emissions (tonnes of CO2e).

TEG = Total Electricity Generated and supplied during the Project Report Period (MWh).

8.2.5 P5 Air Compression

The air compression and management equation applies to projects that replace instrument gas with instrument air systems. Emissions are calculated from the energy and power used to compress and direct air through the device. The quantification applies to scenarios using grid electricity, using onsite-produced fossil fuel electricity and using onsite-produced renewable electricity.

Equation 4: P5 Air Compression

EmissionsAir Compression = ElectricityAir Compression * EFElec Supply

Where:

ElectricityAir Compression = Total quantity of electricity consumed by air compression devices and air management systems for the project report period (MWh). It can be estimated or measured.

EFElec Supply = Emission factor for electricity supplied by grid (integrated or isolated) for Project Report Period (tCO2e / MWh).

Integrated Grid EFElec Supply

For electricity supplied by an Integrated Grid, the Project Proponent must use the appropriate emission intensity factor for the Project Report Period published on the B.C. Ministry of Environment and Climate Change Strategy’s website published in accordance with Schedule E of the Greenhouse Gas Emission Reporting Regulation.

Isolated Grid EFElec Supply

For electricity supplied by an Isolated Grid, the Project Proponent must calculate the appropriate emission factor for each technology / method of Energy Service Process (See Equation 3.1)

15 | D R A F T B . C . V e n t e d E m i s s i o n s R e d u c t i o n s P r o t o c o l

426 Equation 3.1: Emission Factor Electricity Supplied by an Isolated Grid 427

𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑉𝑉𝑉𝑉𝐸𝐸𝐸𝐸 𝑆𝑆𝑆𝑆𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑆𝑆𝑆𝑆,𝐼𝐼𝐼𝐼𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐸𝐸𝐸𝐸𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝑉𝑉𝑉𝑉𝐼𝐼𝐼𝐼 𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐼𝐼𝐼𝐼 =𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑉𝑉𝑉𝑉𝐸𝐸𝐸𝐸𝐺𝐺𝐺𝐺 𝐺𝐺𝐺𝐺𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝑉𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝑉𝑉𝑉𝑉

𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸428429

Where:430431

EmissionsElect Generation = GHG emissions associated with the generation of electricity432in an isolated grid for the project report period. WCI.23 must be used for quantification of CO2 433emissions and WCI.24 for quantification of CH4 and N2O emissions. Use Equation 1 to convert 434CO2, CH4 and N2O emissions to total GHG emissions (tonnes of CO2e). 435𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸 = Total Electricity Generated and supplied during the Project Report Period (MWh). 436

437

8.2.5 P5 Air Compression438

The air compression and management equation applies to projects that replace instrument gas 439with instrument air systems. Emissions are calculated from the energy and power used to 440compress and direct air through the device. The quantification applies to scenarios using grid 441electricity, using onsite-produced fossil fuel electricity and using onsite-produced renewable 442electricity. 443

444Equation 4: P5 Air Compression445

𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐴𝐴𝐴𝐴𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝑃𝑃𝑃𝑃𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝑉𝑉𝑉𝑉𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝑉𝑉𝑉𝑉 = 𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝑇𝑇𝑇𝑇𝐸𝐸𝐸𝐸𝐴𝐴𝐴𝐴𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶 𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝑃𝑃𝑃𝑃𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝑉𝑉𝑉𝑉𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐺𝐶𝐶𝐶𝐶𝐺𝐺𝐺𝐺𝑉𝑉𝑉𝑉 ∗ 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑉𝑉𝑉𝑉𝐸𝐸𝐸𝐸 𝑆𝑆𝑆𝑆𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑆𝑆𝑆𝑆446447

Where: 448

ElectricityAir Compression = Total quantity of electricity consumed by air compression devices and 449

air management systems for the project report period (MWh). It can be estimated or measured.450

𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑉𝑉𝑉𝑉𝐸𝐸𝐸𝐸 𝑆𝑆𝑆𝑆𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑆𝑆𝑆𝑆 = Emission factor for electricity supplied by grid (integrated or isolated) for Project451Report Period (tCO2e / MWh).452

453Integrated Grid 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑉𝑉𝑉𝑉𝐸𝐸𝐸𝐸 𝑆𝑆𝑆𝑆𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑆𝑆𝑆𝑆454For electricity supplied by an Integrated Grid, the Project Proponent must use the appropriate 455emission intensity factor for the Project Report Period published on the B.C. Ministry of 456Environment and Climate Change Strategy’s website published in accordance with Schedule 457E of the Greenhouse Gas Emission Reporting Regulation.458

459Isolated Grid 𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝐸𝑉𝑉𝑉𝑉𝐸𝐸𝐸𝐸 𝑆𝑆𝑆𝑆𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐶𝐸𝐸𝐸𝐸𝑆𝑆𝑆𝑆460For electricity supplied by an Isolated Grid, the Project Proponent must calculate the 461appropriate emission factor for each technology / method of Energy Service Process (See 462Equation 3.1) 463

464

322323 324325

326 327 328 329

330

331

332 333 334 335

336

337

338

339 340 341

342 343

344

345 346 347 348

349

350 351


8.3 LeakageThe GHG sources commonly expected to be material to projects using this Protocol are identified in Figure 1. The Project Plan must confirm that there are no other GHG sources that are material to the Project.

If the Project has an emission source that is potentially material and not included in Figure 1 the Project Proponent must conduct a Leakage assessment as set out in the Regulation section 14(3)(k).

8.4 Project Reductions In this section, quantification results from sub-sections 8.1 to 8.3 are inputs for quantifying the Project Reduction for a project report period.

Equation PR1 Total Baseline Emissions

Baseline Emissions = TB1,m + TB2,m

Where:

TB1,m = GHG emissions from B1 Baseline Vented Gas (tonnes of CO2e).

TB2,m = GHG emissions from B2 Baseline Fuel Consumption (tonnes of CO22e).

Equation PR2: Total Project Emissions

Project Emissions = TP1,m + TP2,m + TP3,m + TP4,m + TP5,m

Where:

TP1,m = GHG emissions from P1 Project Vented Gas (tonnes of CO2e).

TP2,m = GHG emissions from P2 Project Fuel Consumption (tonnes of CO2e).

TP3,m = GHG emissions from P3 Vent Gas Capture (tonnes of CO2e).

TP4,m = GHG emissions from P4 Process Control Electricity (tonnes of CO2e).

TP5,m = GHG emissions from P5 Air Compression (tonnes of CO2e).

Total Project Reduction from a Project is then calculated using Equation PR3:

Equation PR3: Project Reduction

Project Reduction = Baseline Emissions – Project Emissions – Leakage Emissions

Total Project Reduction is reported as a positive value and net emissions increase are reported as a negative value.

352

353 354 355

356 357

358

359 360

361

362

363

364

365

366

367

368

369

370

371

372

373

374

375

376

377 378


9.0 PROJECT REDUCTION ESTIMATES In accordance with Section 14(3)(I) of the Regulation, the Project Plan must include an estimate of the expected Project Reduction to be achieved during the Project Crediting Period. In the Project Plan, the Project Proponent must include the estimated Project Reduction for each Project Report Period. The Project Proponent must explain anticipated variability of the Project Reduction across Project Report Periods.

379

380 381 382 383 384


10.0 DATA COLLECTIONIn the Project Plan, the Project Proponent must detail how data will be collected and managed in accordance with ISO 14064-2:06, sections 5.9 and 5.10 over the Crediting Period and record retention period established in section 27 of the Regulation. The data collection and Monitoring approach must be validated and followed throughout the Crediting Period. Measurement must be in accordance with WCI.25 Sampling, Analysis and Measurement Requirements.

Electricity emission factors must be updated for each Project Report Period. Total electricity consumed must be measured continuously using an electricity meter approved by Measurement Canada.

385

386 387 388 389 390

391 392