GHG Report Tourmaline Oil Gundy Creek Gas Plant Waste Heat

GHG Report Template for CSA Standards GHG CleanProjects® Registry

Version 1.0 – September 2009

GHG Report

Tourmaline Oil Gundy Creek Gas Plant Waste Heat Recovery

Offset Project

Project Developer:

Tourmaline Oil Corp

Prepared by:

Modern West Advisory Inc.

Date:

March 26, 2021

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T A B L E O F C O N T E N T

Table of Content .............................................................................................................................. i

1. Introduction ....................................................................................................................... 1

1.1. Relevance ........................................................................................................................ 3

1.2. Completeness ................................................................................................................... 3

1.3. Consistency ..................................................................................................................... 3

1.4. Accuracy .......................................................................................................................... 3

1.5. Transparency ................................................................................................................... 3

1.6. Conservativeness ............................................................................................................. 3

2. Project Description ............................................................................................................ 3

2.1. Project title ...................................................................................................................... 3

2.2. The project’s purpose(s) and objective(s) are: ................................................................ 4

2.3. Expected lifetime of the project ...................................................................................... 5

2.4. Type of greenhouse gas emission reduction or removal project ..................................... 5

2.5. Legal land description of the project or the unique latitude and longitude ..................... 5

2.6. Conditions prior to project initiation ............................................................................... 5

2.7. Description of how the project will achieve GHG emission reductions or removal

enhancements .............................................................................................................................. 5

2.8. Project technologies, products, services and the expected level of activity .................... 5

2.9. Total GHG emission reductions and removal enhancements, stated in tonnes of CO2 e,

likely to occur from the GHG project (GHG Assertion) ............................................................. 6

2.10. Identification of risks ................................................................................................... 6

2.11. Roles and Responsibilities ........................................................................................... 6

2.12. Any information relevant for the eligibility of the GHG project under a GHG

program and quantification of emission reductions .................................................................... 7

2.13. Summary environmental impact assessment ............................................................... 8

2.14. Relevant outcomes from stakeholder consultations and mechanisms for on-going

communication. ........................................................................................................................... 8

2.15. Detailed chronological plan ......................................................................................... 8

3. Selection and Justification of the Baseline Scenario....................................................... 8

4. Inventory of sources, sinks and Reservoirs (SSRs) for the project and baseline ......... 9

5. Quantification and calculation of GHG emissions/removals ....................................... 16

6. Monitoring the Data information management system and data controls ................ 19

6.1. Data Controls ................................................................................................................. 20

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6.2. Quality Assurance / Quality Control ............................................................................. 21

7. Reporting and verification details .................................................................................. 23

8. References ........................................................................................................................ 24

9. Appendix A ...................................................................................................................... 25

10. Appendix B ....................................................................................................................... 27

11. Appendix C ...................................................................................................................... 28

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1 . I N T R O D U C T I O N

The project includes GHG emissions reductions achieved by reducing fuel consumption through

the use of recovered heat from the exhaust streams of the gas compressor engines operating on site.

This is referred to as “Waste Heat Recovery/WHR” throughout this report. GHG emissions

reductions occur at Gundy Greek Gas Plant owned and operated by Tourmaline Oil located at C-

060-A/094-B-16 in Northeast British Columbia (facility ID: BCGP0026427).

The Gundy Greek Gas Plant processes sweet, raw natural gas and associated inlet liquids and

extract propane plus liquids (C3+) which are then fractionated into the following liquid products:

Propane (C3), Butane (C4) and/or Butane/Propane (C3/C4) and Condensate (C5+). The plant has

been designed to minimize the overall plant energy consumption by employing a highly efficient

plant design using proven turbo expander gas processing technology with a design propane

recovery of 99+%. The plant design also includes systems to recover waste heat from the prime

mover engine exhaust in order to minimize overall energy consumption. The energy recovered from

the engine exhaust accounts for 89% of the energy demand for the facility heat medium system.

Phase 2 of Gundy plant is planned to start up in April 2022. WHR units of the phase 2 plant will

be added to the scope of the offset project when the operation starts.

Six inlet/sales compressors operate at the gas plant. Each compressor engine is equipped with a

waste heat recovery (WHR) system (waste heat exchanger) which is not considered common

industry practice. WHR system takes the energy from the engine exhaust stream and transfers heat

to the process heat medium (PHM), Petrotherm (see Appendix A for Ptrotherm Tech Data). The

heat medium then transfers heat to various parts of the plant through process heat exchangers. The

exhaust stream temperature is ~444°C (831°F) and is cooled to ~204°C (440°F). The exchangers

provide energy into the system heating the Heat Medium fluid to approximately 190 °C. Petrotherm

return temperature is ~170 ℃. Figure 1 below shows a screenshot of the WHR system set up in

SCADA.

Figure 1 Waste Heat Recovery System - SCADA screenshot

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Figure 2 below shows the WHR systems at the Gundy Creek Gas Plant.

Figure 2 Waste Heat Recovery System, Gundy Creek Plant

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1 . 1 . R e l e v a n c e

Greenhouse Gas (GHG) sources, data and methodologies are selected based on existing best

practices that are appropriate and are consistent with the project. The “Quantification Protocol for

Waste Heat Recovery, version 2.0, June 2018” [1] (the Protocol) developed for Alberta Emissions

Offset Registry was used to guide the selection of GHG sources, sinks, reservoirs (GHG SSRs) and

quantification of the associated GHG emissions. This is the most relevant protocol and current good

practice guideline for this project. It was confirmed that the list of potentially relevant SSRs

identified in the Protocol was an appropriate starting point for determining project specific relevant

SSRs and did not exclude any potentially relevant SSRs.

Emission sources and sinks are identified based on the Protocol and are explained in detail in

section 4 of this report.

1 . 2 . C o m p l e t e n e s s

GHG emissions of baseline and project conditions from all identified emission sources are

quantified using the quantification methodology presented in the Protocol.

1 . 3 . C o n s i s t e n c y

The procedures from the Protocol are consistently used to quantify the GHG emissions from all

sources of GHG emissions. Project and baseline scenarios demonstrate equivalent levels of product

or services, and enable meaningful comparisons in GHG-related information.

1 . 4 . A c c u r a c y

The project proponent ensures that the best available quantitative and qualitative data and

information are used. Primary data from fuel/service providers or direct measurements are used as

much as possible to ensure the data are non-biased and have as little uncertainty as reasonably

possible.

1 . 5 . T r a n s p a r e n c y

All data, information, calculations, and assumptions are clearly stated and justified, to facilitate the

verification of the results to a reasonable level of assurance.

1 . 6 . C o n s e r v a t i v e n e s s

The project uses conservative assumptions, values and procedures to ensure that GHG emission

reductions or removal enhancements are not over‐estimated. References on conservativeness are

provided along the report, where applicable.

2 . P R O J E C T D E S C R I P T I O N

2 . 1 . P r o j e c t t i t l e

Tourmaline Oil Gundy Creek Gas Plant Waste Heat Recovery Project.

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2 . 2 . T h e p r o j e c t ’ s p u r p o s e ( s ) a n d o b j e c t i v e ( s ) a r e :

The objective of the Tourmaline Oil Gundy Creek Gas Plant Waste Heat Recovery project, “the

project”, is to process natural gas for eventual sale in a way that:

• Reduces Greenhouse Gas (GHG) emissions; and,

• Improves local air quality including NOx emissions; and,

• Represents a more environmentally and socially responsible approach than conventional

practices.

The project reduces GHG emissions by using recovered heat from compressor engines exhaust

which results in a decreased fuel consumption and consequently decreased GHG emissions at the

plant.

Six inlet/sales compressors operate at the gas plant, and one waste heat exchanger is installed on

each compressor to recover heat from the compressor engine exhaust stream. The compressors and

engines along with the waste heat recovery systems were installed when the plant was constructed

(greenfield installation) in June 2019.

WHR system takes the energy from the engine’s exhaust stream and transfers the heat to the process

heat medium (PHM). Temperature of the exhaust stream from the engine is approximately 444 °C

and is used to heat the process heat medium fluid from ~170 to ~190 °C. The heat medium then

transfers heat to various parts of the plant through process heat exchangers. Recovered heat is used

in various process units such as stabilizer column.

The heat medium fluid used in the system to transfer heat to various process units at the facility is

Petrotherm. Physical and chemical properties of Petrotherm are extracted from the manufacturer’s

technical data sheet (presented in Appendix A).

The amount of recovered heat from the engine exhaust might not be sufficient to provide required

heat to all processes on site. Therefore, a natural gas heater is available at the plant to provide make-

up heat when required. The efficiency of the natural gas fired heaters is 82% based on the heater

specification sheet (HHV basis) (the heater specification sheet is provided in Appendix B). Offset

credits are only generated for the part of process heat provided by the recovered heat from engine

exhaust stream, and the natural gas heater provided heat (if any) is not included.

Heat medium flowrate, inlet and outlet temperatures, and WHR unit operating hours (compressor

operating hours) are monitored and recorded manually every day (once or twice per day). It should

be noted that the compressor operating hours were not monitored daily until September 2020.

However, cumulative operating hours of the compressors were recorded every week from January

to August. The recorded cumulative operating hours are used to calculate the monthly operating

hours of the units for January to August period. The recorded data is then used for emission

reduction calculation as explained in section 5.

Data related to these activities will be directly monitored, and calculations are performed based on

the WHR Protocol and ISO 14064-2, to ensure that an accurate and conservative assessment of the

corresponding emission reductions will be achieved.

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2 . 3 . E x p e c t e d l i f e t i m e o f t h e p r o j e c t

Expected lifetime of the project is 15-20 years. The project proponent intends to generate carbon

offsets until the project ceases to respect the principle of additionality or until the WHR units have

reached the end of their useful life.

2 . 4 . Ty p e o f g r e e n h o u s e g a s e m i s s i o n r e d u c t i o n o r r e m o v a l p r o j e c t

The project is an aggregated project that is classified as a waste heat recovery project type. The

project results in a reduction in GHG emissions by replacing part of natural gas that would have

been used to provide process heat in the absence of the project by the recovered heat from

compressor engine exhaust stream.

2 . 5 . L e g a l l a n d d e s c r i p t i o n o f t h e p r o j e c t o r t h e u n i q u e l a t i t u d e a n d

l o n g i t u d e

Tourmaline Oil is the sole owner/operator of Gundy Gas plant and the waste heat recovery offset

project. Evidence of ownership and operation is provided in extract from the British Columbia Oil

and Gas Commission Database (FACINDEX) file, which evidences all owned and operated

compression assets within the province.

Gundy Creek Gas plant is located at C-060-A/094-B-16 in Northeast British Columbia

(BCGP0026427).

2 . 6 . C o n d i t i o n s p r i o r t o p r o j e c t i n i t i a t i o n

This is a greenfield project, therefore, conditions prior to project initiation is not applicable here.

The incorporation of waste heat recovery equipment is not standard practice for greenfield gas

plants. In the absence of the project, engine exhaust waste heat would have been released to the

atmosphere as waste heat, and the required heat for the process would have been entirely provided

using a natural gas heater.

2 . 7 . D e s c r i p t i o n o f h o w t h e p r o j e c t w i l l a c h i e v e G H G e m i s s i o n

r e d u c t i o n s o r r e m o v a l e n h a n c e m e n t s

The project will result in a reduction in carbon dioxide, methane, and nitrous oxide emissions from

combustion of natural gas by providing the required process heat with recovered heat obtained from

the compressor engine exhaust gas. In the baseline condition, all the process heat requirement

would have been provided by natural gas combusted in a NG heater. In the project condition, the

process heat requirement that was provided by NG heater is provided by recovered heat from the

engine exhaust stream. This will result in a reduction in NG consumption by the heaters and

consequently a decrease in GHG emissions.

2 . 8 . P r o j e c t t e c h n o l o g i e s , p r o d u c t s , s e r v i c e s a n d t h e e x p e c t e d l e v e l o f

a c t i v i t y

The project involves installing waste heat recovery units to recover heat from engine exhaust gas

stream and use it to heat the process heat medium. A waste heat exchanger is installed to transfer

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heat from the exhaust stream to the process heat medium. Heat is then transferred from the process

heat medium to various process units at the facility via process heat exchangers.

GHG emissions reductions are achieved by replacing the natural gas consumed for process heat by

recovered heat from the engine exhaust. Project is designed to deliver the same levels of products,

services, and activity as the baseline condition.

2 . 9 . To t a l G H G e m i s s i o n r e d u c t i o n s a n d r e m o v a l e n h a n c e m e n t s , s t a t e d

i n t o n n e s o f C O 2 e , l i k e l y t o o c c u r f r o m t h e G H G p r o j e c t ( G H G

A s s e r t i o n )

A summary of the total GHG reductions achieved in 2020 is provided in the Table 1 below. The

crediting period covered in this GHG report includes the GHG reductions from January 1, 2020 to

December 31, 2020.

Table 1 Emissions Reduction Summary

Vintage Year PFC

(tCO2e)

HFC

(tCO2e)

SF6

(tCO2e)

CO2

(tCO2e)

CH4

(tCO2e)

N2O

(tCO2e)

Total

(tCO2e)

January 1 – December 31,

2020 0 0 0 19,110 570 103 19,783*

* Total number may not add up because of rounding.

2 . 1 0 . I d e n t i f i c a t i o n o f r i s k s

There are a number of risks associated with the project that are listed below along with the risk

mitigation and management measures:

1) WHR maintenance or shutdown: When the waste heat recovery unit is shut down, the heat

from the engine exhaust is not utilized and is vented to the atmosphere as it would have been in the

baseline condition. Natural gas-fired heaters are used to provide the necessary heat under such

conditions. No offset credits will be generated when the WHR unit is not operating. This

information will be identified during quality assurance / quality control tracking.

2) Compressor shutdown: Similar to the risk of WHR unit shutdown, if the compressor is not

operating and no source of energy (i.e., waste energy) exists, the natural gas-fired heaters will be

used to heat the medium fluid. No offset credits will be generated when the compressor is not

operating. This information will be identified during quality assurance / quality control tracking.

2 . 1 1 . R o l e s a n d R e s p o n s i b i l i t i e s

Project proponent(s):

Nigel Campbell

Tourmaline Oil Corp.

[email protected]

(403) 767-3550

Unit 3700, 250 6 ave SW, Calgary, AB

mailto:[email protected]

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Authorized project contact(s):

Zainab Dadashi


[email protected]

(403) 400-7106

Unit 600, 505 2nd street SW, Calgary, AB

Person(s) writing the GHG Report:

Zainab Dadashi


[email protected]

(403) 400-7106


Person(s) providing the quantification services:

Zainab Dadashi


[email protected]

(403) 400-7106


Person(s) responsible for the content of the GHG Report and the GHG Assertion:

Nigel Campbell

Tourmaline Oil Corp.

[email protected]

(403) 767-3550

Unit 3700, 250 6 ave SW, Calgary, AB

2 . 1 2 . A n y i n f o r m a t i o n r e l e v a n t f o r t h e e l i g i b i l i t y o f t h e G H G

p r o j e c t u n d e r a G H G p r o g r a m a n d q u a n t i f i c a t i o n o f e m i s s i o n

r e d u c t i o n s

Installing a waste heat recovery system in a greenfield gas plant is not common practice and

involves economic and technological barriers. The facilities included in this report do not currently

face any GHG emission reduction obligations. Other than potential offset credits that may be

generated, the facility does not stand to benefit from any climate change incentives. The

“Quantification Protocol for Waste Heat Recovery, version 2.0, June 2018” [1] has been used to

guide the quantification and reporting of the GHG emissions reductions resulting from the project.

Identifying GHG reduction and removal projects, baseline and project conditions, GHG reduction

quantification, data management and monitoring, GHG reporting and verification of the GHG

reduction project are inline with ISO 14064 guidelines and requirements.





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2 . 1 3 . S u m m a r y e n v i r o n m e n t a l i m p a c t a s s e s s m e n t

An environmental impact assessment was not required for the project as the associated

environmental impacts as a result of implementing the project are limited to the GHG emissions.

2 . 1 4 . R e l e v a n t o u t c o m e s f r o m s t a k e h o l d e r c o n s u l t a t i o n s a n d

m e c h a n i s m s f o r o n - g o i n g c o m m u n i c a t i o n .

Stakeholder consultations were not required for this Project. The Quantification Protocol for Waste

Heat Recovery used to quantify VERRs from the project was developed following a transparent

consultation process with industry stakeholders to ensure the relevance, accuracy,

conservativeness, consistency, and transparency of the protocol.

2 . 1 5 . D e t a i l e d c h r o n o l o g i c a l p l a n

Gundy Creek Gas Plant started operating in June 2019. The WHR units were installed at the same

time the gas plant was constructed. The project started generating offset credits since the project

start date and will continue to generate offset credits until the project ceases to respect the principle

of additionality or until the WHR units have reached the end of their useful life. This GHG report

presents the offset credits for 2020 as a result of the project.

3 . S E L E C T I O N A N D J U S T I F I C A T I O N O F T H E B A S E L I N E

S C E N A R I O

In the baseline scenario for the waste heat recovery project, all the process heat required on site

(including heat provided by recovering heat from engine exhaust stream in the project conditions),

is provided by natural gas heaters, and waste heat from engine exhaust stream is released to the

atmosphere. Natural gas heaters are available on site which can be used to compensate for process

heat requirement in the absence of a WHR system. This is the most common scenario when a WHR

system is not installed to utilize available heat from engine exhaust stream. Another potential option

that could be considered for providing the required process heat in the baseline (in the absence of

a WHR system) is to install individual burners on each piece of equipment that needs process heat.

After reviewing both potential baseline scenarios, using one NG heater to provide the required

process heat is selected for two main reasons. The first reason is that using individual burners makes

the process more complicated by installing multiple pieces of equipment instead of one. The second

reason is that the individual burners typically have an efficiency between 65-75%, which is less

efficient than using one large heater with 82% efficiency to provide heat to the whole plant.

There is no economic, technology, data limitation, or legislative barrier to the baseline condition.

The protocol explains that in the absence of a WHR system, fossil fuel is combusted to provide the

required heat which is in line with the baseline assumption in this project.

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4 . I N V E N T O R Y O F S O U R C E S , S I N K S A N D R E S E R V O I R S

( S S R S ) F O R T H E P R O J E C T A N D B A S E L I N E

The identification of sources and sinks in the baseline and project conditions is based on the

guideline provided in the Quantification Protocol for Waste Heat Recovery [1] which is based on

ISO 14064-2 standards.

Process flow diagrams for baseline and project conditions are presented in Figures 3 and 4. A

description of each source/sink and its classification as controlled, related or affected along with

the reason for exclusion/inclusion are provided in Table 2.

Figure 3 Process Flow Diagram for Baseline Condition (adapted from [1])

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Figure 4 Process Flow Diagram for Project Condition (adapted from [1])

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Table 2 Inventory of sources and Sinks

Identified Source and Sinks Baseline Project

Include or

Exclude from

Quantification

Justification for Exclusion and Inclusion

Upstream Sources and Sinks

P1 Fuel Extraction and Processing N/A Related Include As per protocol: Included as there may be increased

emissions associated with fuel extraction and

processing during the project. B1 Fuel Extraction and Processing Related N/A Include

P2 Fuel Delivery N/A Related Exclude As per protocol: Excluded as the emissions from

transportation are likely greater under the baseline

condition and it is conservative to exclude them. B2 Fuel Delivery Related N/A Exclude

P3 Generation of Waste Heat N/A Related Exclude As per protocol: Excluded as by definition, the

generation of this component of the heat is deemed as

a waste produced as part of another process. As such,

the project and baseline condition are defined to be

functionally equivalent.

B3 Generation of Waste Heat Related N/A Exclude

P4 Generation of Supplementary

Heat and Power N/A Related Include

Included as there are increased greenhouse gas

emissions from the generation of supplemental heat

and power during the project. However, this value is

zero in the project condition, as there are no use of

supplementary heat and power in the project condition.

P5 Distribution of Waste Heat Related N/A Exclude

As per protocol: Excluded as any incremental fossil

fuel usage or electricity usage in the project condition

associated with the recovery and utilization of waste

heat will be captured under P4, P9, or P13.

P8 Development and Processing of

Unit Material Inputs N/A Related Exclude

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Include or

Exclude from

Quantification


B6 Development and Processing of

Unit Material Inputs Related N/A Exclude

As per protocol: Excluded as by definition, must be

functionally equivalent to allow for the application of

the protocol.

P13 Electricity Usage N/A Related Include Included as there are increased greenhouse gas

emissions from the usage and or displacement of

electricity during the project. However, this value is

zero in the project condition, as there is no use of

electricity in both project and baseline conditions.

B11 Electricity Usage/

Displacement Related N/A Include

On-site Sources and Sinks

P6 Generation of Heat and Power N/A Controlled Exclude

As per protocol: Excluded as any change in fossil fuel

usage caused by the operation of the waste heat

recovery project can be accounted for under P4.

B4 Generation of Heat and Power Controlled N/A Include N/A

P7 Heat Transfer or Power

Conversion N/A Controlled Exclude

As per protocol: Excluded as any change in fossil fuel

usage or electricity usage from the baseline to the

project condition (e.g. supplemental fossil fuels used to

operate the waste heat recovery unit) will be captured

under P4/B4 and P13/B11, so P7 and B5 must be


B5 Heat Transfer or Power

Conversion Controlled N/A Exclude

P9 Unit Operation N/A Controlled Exclude As per protocol: Excluded as any change in fossil fuel

usage or electricity usage from the baseline to the

project condition (e.g. supplemental fossil fuels used to

operate the waste heat recovery unit) will be captured B7 Unit Operation Controlled N/A Exclude

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Include or

Exclude from

Quantification


under P4/B4 and P13/B11, so P9 and B7 must be


P10 Facility Operation N/A Controlled Exclude As per protocol: Excluded as the facility operation is

not typically impacted by the implementation of the

project and as such the baseline and project conditions

will be functionally equivalent. B8 Facility Operation Controlled N/A Exclude

P11 On-Site Electricity Generation N/A Controlled Exclude As per protocol: Excluded as the change in baseline

emissions related to electricity usage/generation can be

accounted for under B11 and any incremental fossil

fuel usage in the project condition can be accounted for

under P4 or P13. Most site configurations will not

include electricity generation equipment in the baseline

as those facilities are typically large emitters that are

already regulated under the Carbon Competitiveness

Incentives Regulation.

B9 On-Site Electricity Generation Controlled N/A Exclude

Downstream Sources and Sinks

P12 Development and Processing

of Unit Material Outputs N/A Related Exclude As per protocol: Excluded as by definition, these

components must be functionally equivalent to allow

for the application of the protocol. B10 Development and Processing

of Unit Material Outputs Related N/A Exclude

Other Sources and Sinks

P14 Development of Site N/A Related Exclude As per protocol: Emissions from development of site

are not material given the long project life and the

minimal development of site typically required. B12 Development of Site Related N/A Exclude

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Include or

Exclude from

Quantification


P15 Building Equipment N/A Related Exclude As per protocol: Emissions from building of

equipment are not material given the long project life

and the minimal building equipment typically required. B13 Building Equipment Related N/A Exclude

P16 Transportation of Equipment N/A Related Exclude As per protocol: Emissions from transportation of

equipment are not material given the long project life

and the minimal transportation of equipment typically

required. B14 Transportation of Equipment Related N/A Exclude

P17 Construction on Site N/A Related Exclude As per protocol: Emissions from construction on site


minimal construction on site typically required. B15 Construction on Site Related N/A Exclude

P18 Testing of Equipment N/A Related Exclude As per protocol: Emissions from testing of equipment


minimal testing of equipment typically required. B16 Testing of Equipment Related N/A Exclude

P19 Site Decommissioning N/A Related Exclude

As per protocol: Emissions from decommissioning of

site are not material given the long project life and the

minimal decommissioning typically required.

B17 Site Decommissioning Related N/A Exclude

As per protocol: Emissions from decommissioning

are not material for the baseline condition given the

minimal decommissioning typically required.

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Sources and sinks that are not expected to change between baseline and project condition have been

excluded from the quantification. It is assumed that excluded activities will occur at the same

magnitude and emission rate during the baseline and project and will therefore be functionally

equivalent.

Emissions that increase or decrease as a result of the project must be included and associated

greenhouse gas emissions must be quantified as part of the project condition.

Any natural gas consumed by natural gas heaters to generate heat in the project condition (make-

up heat or if WHR unit is not operating) is equivalent to natural gas consumption in the baseline

condition, and therefore not included in emission reduction calculations.

According to Table 2, baseline emission sources included in the quantification are as follow:

1) B1: Fuel Extraction and Processing

This emission source accounts for extraction and processing emissions of natural gas consumed in

the baseline condition if waste heat recovery had not occurred. The amount of natural gas

consumption in baseline condition is calculated using the amount of recovered heat used in the

project and the efficiency of natural gas heater that would have been used in the absence of the

project. This is further explained in section 5.

2) B4: Generation of Heat and Power

This emission source accounts for NG combustion emissions in the baseline condition had the

project not occurred. The amount of NG to estimated B4 is the same as B1 emission source above.

3) B11: Electricity Usage/Displacement

Since no electricity is generated using recovered heat on site, this emissions source is equal to zero.

Project emission sources included in the quantification are as follows:

4) P1: Fuel Extraction and Processing

Since no additional fuel is consumed in the project, this emission source is equal to zero.

5) P4: Generation of Supplementary Heat and Power

Since no supplementary heat and power is generated in the project, this emission source is equal to

zero (as explained earlier, in case the recovered heat from engine exhaust stream is not sufficient

to provide 100% of the required heat on site, natural gas heaters will be used in the project to

supplement the recovered heat. However, NG combustion in the heaters is not included in the

quantification of the project emissions because an equivalent amount of natural gas would have

been consumed in the baseline condition to provide the same amount of heat therefore resulting in

the same level of GHG emissions. In other words, only the part of heat requirement that is replaced

by recovered heat in the project is included in the quantification.).

6) P13: Electricity Usage

Since the WHR system consists of a heat exchanger for transferring heat between the exhaust

stream and the process heat medium, no electricity is required for WHR system operation.

Therefore, P13 is equal to zero.

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Quantification approach for estimating non-zero emission sources (i.e., B1 and B4) is explained in

section 5.

5 . Q U A N T I F I C A T I O N A N D C A L C U L A T I O N O F G H G

E M I S S I O N S / R E M O V A L S

Emission reduction quantification for the waste heat recovery project is carried out using the

quantification methodology described in the Quantification Protocol for Waste Heat Recovery [1].

Emission factors that are applicable to BC emissions reporting are extracted from the relevant

documents when available.

Table 3 below shows emissions sources and sinks identified for quantification.

Table 3 Identified Sources and Sinks

Sources and Sinks Related Project/Baseline activities

On-site

B4 Generation of Heat and Power Combustion of fuel in natural gas-fired heaters

to provide heat to the medium fluid

Upstream

B1 Fuel Extraction and Processing

Extraction of natural gas for use as fuel in

natural gas-fired heaters in the baseline

conditions

Net Emission Reduction = Baseline Emissions – Project Emissions

Net Emission Reduction = B1 + B4

B1 – Fuel Extraction and Processing

GHG emissions associated with fuel extraction and processing in baseline conditions is estimated

using the equation below:

EF Fueli , CO2/CH4/N2O is CO2/CH4/N2O emissions factor for fuel including production and processing.

Emission factors are extracted from the Carbon Offset Emission Factors Handbook [2] and shown

in Table 4. GWPCH4 / N2O is the global warming potential of CH4 and N2O gases as presented in

British Columbia Greenhouse Gas Reduction Targets Act, 25 and 298 for CH4 and N2O

respectively [3].

Natural gas is the only type of fuel combusted to provide heat in the baseline. Vol. Fueli is the

volume of natural gas that is combusted in baseline condition (part of natural gas consumption that

is replaced by recovered heat in the project is considered here). The volume of natural gas is

calculated using the amount of heat provided by waste heat recovery system and the efficiency of

17



natural gas heaters that would have been used to provide the same amount of heat in the baseline

condition as shown in the equation below:

Heat output is the amount of heat provided by the heat recovery system, estimated based on

thermodynamic properties of the heat transfer medium (heat capacity of fluid) (Cp), measured fluid

circulation rates in the heat distribution system (m), and based on the measured temperature

differences between the supply and return fluid in the heat transfer loop (Delta T). WHR unit

operating hours and fluid circulation rate along with its inlet and outlet temperature are monitored

and recorded manually by field operators every day (Jan-Aug operating hours are not recorded

daily, but cumulative operating hours are recorded weekly and used in the calculations). There are

1 or 2 data points recorded per day (temperature and flowrate data).

During 2020, inlet temperature to the WHR system (return fluid temperature) was not tracked

continuously. The return fluid usually has a fixed range of temperature at normal plant operation.

Therefore, the field staff started tracking the inlet temperature in January 2021 by installing a new

temperature transmitter, to specify a temperature range for the return fluid and use that as an

average inlet temperature for the whole 2020 year. The inlet temperature was tracked for 36 days

(from Jan 17 2021, to Feb 24 2021), and the temperature range during this period was between 168

and 170 ℃ (170 ℃ for most days). We use 170 ℃ as the inlet temperature to the WHR unit for

2020 quantification, because this will provide the most conservative estimate of the emission

reductions.

After reviewing 2020 data, it was observed that temperature and flowrate data are missing for a

number of days during 2020. The waste heat recovery system was operating during those days as

indicated by the recorded operating hours of the compressors. Therefore, some amount of heat was

recovered on those days. To estimate the amount of recovered heat for days with missing data in

each month, we assign the lowest flowrate that was recorded during that month to those days. This

provides the most conservative recovered heat estimate for those days.

EfficiencyHeat Gen is the efficiency of the heat generation equipment (i.e., natural gas heaters) in the

baseline. NG heater efficiency is 82% according to the heater specification sheet provided in

Appendix B. HHVFuel i is the higher heating value of the fuel obtained from gas analysis performed

annually, semi-annually or monthly on the NG fuel at the facility and is used to convert fuel volume

to its energy content.

Table 4 Emission Intensity of Fuel Extraction and Production

Source Emission Factors

kg CO2 / m3 kg CH4 / m3 kg N2O / m3

Natural Gas Extraction 0.043 0.0023 0.000004

Natural Gas Processing 0.090 0.0003 0.000003

18



B4 – Generation of Heat and Power

GHG emissions associated with natural gas combustion in baseline conditions is estimated using

the equation below:

EF Fueli , CH4/N2O is CH4/N2O emissions factor for combustion of each type of fuel. Emission factors

are extracted from Western Climate Initiative document, WCI.020 [4]. WCI quantification methods

are the standard emission estimation and reporting methodology for mandatory emission reporting

in British Columbia. EF Fueli , CO2 is CO2 emissions factor for combustion and is determined by the

carbon content of the fuel gas which is obtained from the fuel gas composition data. This is the

most accurate method for estimating site specific CO2 emission factor for fuel gas.

GWPCH4 / N2O is the global warming potential of CH4 and N2O gases as presented in British Columbia

Greenhouse Gas Reduction Targets Act (25 for CH4 and 298 for N2O) [3].

Vol. Fueli is the volume of natural gas that is combusted to generate heat and power in baseline

condition. The volume of natural gas is calculated using the same approach explained for B1

emission estimation above.

Table 5 Emission Intensity of NG Combustion

Source Emission Factors

kg CO2 / m3 kg CH4 / m3 kg N2O / m3

Natural Gas Combustion 2.077* 0.000037 0.000033 *Calculated

Sample Calculations

Collected data for one specific month is used here to demonstrate how emission reduction is

calculated for the offset project.

Input data:

• Petrotherm inlet temperature = 170.0°C

• Petrotherm outlet temperature = 190.0 °C

• Petrotherm volume flowrate = 3900 m3/day

• WHR operating hours = 712 hrs/month

• Petrotherm density = 760 kg/m3

[calculated as a function of temperature – average inlet and outlet temperature]

• Petrotherm specific heat = 2.45 kJ/kg.K

[calculated as a function of temperature – average inlet and outlet temperature]

• Fuel HHV = 0.041035 GJ/m3

19



• NG heater efficiency = 0.82

Density and specific heat capacity of Petrotherm are calculated at the average temperature using

the following equation:

Density (kg/L) / Specific Heat (Cp) (kJ/kg.K) = A + BT

Coefficients Density Heat Capacity

A 0.880 1.752

B -6.69E-04 3.88E-03

Density and specific heat functions are obtained using the provided data in the Manufacturer’s

Technical Sheet.

Cp = 1.752 + 3.88 * 10-3 * ((170.0+190.0)/2) = 2.45 kJ/kg.K

Density = 0.880 – 6.69 * 10-4 * ((170.0+190.0)/2) = 0.760 kg/L

Heat output = 3900 m3/day * 1/24 day/hr * 712 hr/month * 2.45 kJ/kg.K * (190.0 – 170.0) °C *

10-6 GJ/kJ = 4310 GJ

Vol. Fuel = 4310 / 0.82 / 0.041035 GJ/m3 = 1.28 * 105 m3

B1 : Emission Fuel Extraction and Processing = (1.28 * 105 (0.043 + 0.090) + 1.28 * 105 * (0.0023 + .0003)

* 25 + 1.28 * 105 * (0.000004 + 0.000003) * 298) / 1000 = 25.6 tCO2e

B4 : Emission Generation of Heat and Power = (1.28 * 105 * 2.077 + 1.28 * 105 * 0.00037 * 25 + 1.28 * 105

* 0.000033 * 298) / 1000 = 269 tCO2e

Net Emission Reduction = Baseline Emissions – Project Emissions = B1 + B4 – 0 = 25.6 + 269.0

– 0 = 294.6 tCO2e

6 . M O N I T O R I N G T H E D A T A I N F O R M A T I O N M A N A G E M E N T

S Y S T E M A N D D A T A C O N T R O L S

The project proponent has a monitoring plan in place that is intended to guide the process of

collecting GHG data for project and baseline, allowing a complete, accurate and transparent

quantification of GHG reductions. Monitored data will be primarily managed by the field staff and

Environmental Coordinator. The Environmental Coordinator will access Tourmaline Oil in-house

data systems, data collected from the field, as well as monitored data through the ProTrend

Database (Gas Analysis Reports).

All the required operational input data for the Waste Heat Recovery offset project are tracked and

recorded in the Tourmaline Oil internal data management system. The list of input data that are

tracked during the project includes:

1) Process heat medium fluid inlet temperature

Inlet temperature data is monitored and recorded manually, once or twice per day.

Recorded data are stored in data collection spreadsheets and shared with the Environmental

Coordinator (recording the inlet temperature started in 2021, as explained in section 5.

20



Average inlet temperature is determined based on the collected data in 2021 and use for

2020 quantification).

2) Process heat medium fluid outlet temperature

Outlet temperature data is monitored and recorded manually, once or twice per day.

Recorded data are stored in data collection spreadsheets and shared with the Environmental

Coordinator.

3) Process heat medium fluid flowrate

Flowrate data is monitored and recorded manually, once or twice per day. Recorded data

are stored in data collection spreadsheets and shared with the Environmental Coordinator.

4) WHR units operating hours

Operating hours are tracked daily starting September 2020 and recorded manually. For Jan-

Aug period, cumulative operating hours were recorded weekly. Recorded data are stored

in data collection spreadsheets and shared with the Environmental Coordinator.

5) Gas analysis including gas composition, density and energy content.

Gas sampling and analysis is conducted by AGAT laboratory and all the records are stored

in ProTrend database. Data is validated by ProTrend. Reports are generated and distributed

through a secure and controlled automatic process. Tourmaline Oil Environmental

Coordinator has online access to the gas analysis data.

The temperature transmitters and flowmeters of the WHR units were calibrated according to the

manufacturer’s recommendations when the units were started up in 2019, and Tourmaline Oil will

conduct calibration every 5 years going forward as recommended by the manufacturer. The 2019

calibration reports are provided in Appendix C.

The WHR units are very low maintenance and include greasing of the actuators only, which is done

by the field operators when required.

6 . 1 . D a t a C o n t r o l s

In order to ensure sound data integrity, completeness, accuracy and validity, the following measures

are undertaken by the Project Proponent.

• Project education is provided to relevant staff members to ensure data collection is

completed in line with the Project requirements.

• All data is captured on a daily basis (depending on the data point) and compiled once for

each crediting period before the verification process.

• This information is populated into the Quality Assurance/Quality Control document for

this Project and scrutinized for anomalies by two Tourmaline Oil employees not directly

involved in the data collection process.

• Data captured on-site by either Proponent employees or third-party vendors are held as

hard copies in the Proponent field office following their input into the appropriate data

management system.

• The copies are retained per the Proponent’s corporate data retention policy.

21



• Prior to the completion of the annual Emission Reduction Calculator, data is further

scrutinized by a third-party vendor who is not responsible for verification but has distinct

knowledge of the project.

Data quality management will rely to a large degree on the standard quality management practices

already in place within Tourmaline Oil Corp. Some additional requirements are described in the

following sections, and in the below table:

Table 6 Data Table

Data Process

Inlet/Outlet Temperature Data is manually recorded on site, and then digitized at the

office. Tourmaline reviews the data internally and sends the

data to third-party consultant who will review the data and use

them to quantify the Project’s GHG emissions reductions.

Flowrate

Operating hours

Gas Analysis

Gas sampling and analysis is conducted by AGAT laboratory

and all the records are stored in ProTrend database. Data is

validated by ProTrend. Reports are generated and distributed

through a secure and controlled automatic process. Tourmaline

Oil Environmental Coordinator has online access to the gas

analysis data.

Site Specific Data

Site specific data are obtained from a number of documents

including equipment manuals, site P&IDs and field data

collection.

6 . 2 . Q u a l i t y A s s u r a n c e / Q u a l i t y C o n t r o l

The Tourmaline Oil Waste Heat Recovery Offset Project Quality Assurance / Quality Control

(QA/QC) procedure is built to provide an annual review of the offset project data collected in a

given calendar year. There are at least two data reviewers who are Project Proponent employees

and who are intimately familiar with the project. The designated data reviewers will perform the

following tasks:

• Maintaining corporate oversight over the offset project and ensuring that multiple internal

employees are collecting the appropriate project information on an ongoing basis.

• Being intimately aware of the project data requirements as well as overall field operations

and being able to comment on data quality and influencing factors should data anomalies

be discovered.

• Maintaining oversight over the operation and contributing to the coordination of field data

collection.

22



• Having an intimate understanding of field operations related to the offset project and the

ability to review the quality of the data and explain any potential anomalies that may result

from field activities/factors.

This QA/QC review will be completed regularly prior to the serialization of new offsets. The

QA/QC documents will be reviewed by a third-party verifier to ensure the appropriate process is

followed and to ensure the quality of data meets the verification requirements.

23

7 . R E P O R T I N G A N D V E R I F I C A T I O N D E T A I L S

This GHG Report is prepared in accordance with ISO 14064‐2, Alberta Waste Heat Recovery

protocol, and with the GHG CleanProjects® requirements.

The first crediting period for this project is January 1st, 2020 to December 31st, 2020. Required

input information including inlet and outlet temperature and flowrate of the process heat medium

(TEG), and operating hours of the WHR unit are collected and used in an Emission Reduction

Calculator to calculate the emissions reductions during the crediting period.

Total GHG reduction during the crediting period is 19,783 tCO2e as shown in Table 7 below.

Table 7 Emissions Reduction for January 1st - December 31st, 2020 crediting period

Crediting Period PFC

(tCO2e)

HFC

(tCO2e)

SF6

(tCO2e)

CO2

(tCO2e)

CH4

(tCO2e)

N2O

(tCO2e)

Total

(tCO2e)

January 1 – December 31 0 0 0 19,110 570 103 19,783

The emission reduction is a result of 6 WHR units installed and operated at Gundy Greek Gas Plant

owned and operated by Tourmaline Oil located at C-060-A/094-B-16 in Northeast British

Columbia.

Brightspot Climate Inc. is engaged to verify the GHG emission reductions and ensure that the

emissions removals and reductions from the Project are not overestimated and that the number of

VERRs that are reported are real.

The verifier is an independent third‐party. The Verification Report will:

• Conform to ISO 14064‐3 and ISO 14065 standards.

• Include a signed Verification Statement.

• Be prepared by an independent third‐party.

• Provide details on how conflicts of interest issues are managed or mitigated.

• Demonstrate that the verification body is competent to perform the verification of the GHG

project that includes the GHG Report, GHG Assertion(s), and the calculations of the GHG

emission reductions or removal enhancements.

• Include in its scope the fact that the project conforms to the requirements of ISO 14064‐2.

• Verify the project to a reasonable level of assurance, including all GHG Assertion(s) and

calculations of GHG emission reductions or removal enhancements.

24



8 . R E F E R E N C E S

[1] Government of Alberta, 2018, Quantification protocol for waste heat recovery. Version 2.0.

Available online at https://open.alberta.ca/publications/9781460138618

[2] Government of Alberta, 2019, Carbon offset emission factors handbook. Version 2.0.

Available online at https://open.alberta.ca/publications/9781460146064

[3] B.C. Reg. 392/2008, Greenhouse Gas Reduction Targets Act, CARBON NEUTRAL

GOVERNMENT REGULATION, Available online at

http://www.bclaws.ca/civix/document/id/complete/statreg/392_2008

[4] Western Climate Initiative, 2011, Final Essential Requirements of Mandatory Reporting, 2011

Amendments for Harmonization of Reporting in Canadian Jurisdictions, Available online at

https://www2.gov.bc.ca/assets/gov/environment/climate-change/ind/quantification/wci-2012.pdf

https://open.alberta.ca/publications/9781460138618

https://open.alberta.ca/publications/9781460146064

http://www.bclaws.ca/civix/document/id/complete/statreg/392_2008

https://www2.gov.bc.ca/assets/gov/environment/climate-change/ind/quantification/wci-2012.pdf

25



9 . A P P E N D I X A

26



27



1 0 . A P P E N D I X B

28



1 1 . A P P E N D I X C

CDN Controls Ltd. Version: 1.1

Custodian: QAQC Department14.37 TRANSMITTER CHECKLIST & TEST

RECORD

Revision date: 5/22/2018

Client: Tourmaline Location: Gundy Plant Area/System: 510

Device Tag:TIT-5110-1

Type:temperature

transmitterDate:

2019-04-21

Manufacturer:ROSEMOUNT

Model:644HAK6XAJ6M5F6Q4

Description:E-5110 WASTE HEAT

RECOVERY EXCHANGER

OUTLET

P&ID #: D-MFS-168166-5100-1 Location Dwg: I/O Dwg:

Instr. Range: -100-450 Calib. Range: -50--315.6 Display Range:

Data Sheet:

Burnout

Direction: Serial #:

Mark S-Satisfactory N/A-Not applicable (Any item marked U must before fixed prior to energizing)

Inspection S N/A Procedure S N/A

Stamped SS Tags attached ☒ ☐ Measure Device Voltage ☒ ☐

Wiring Correct and Termination Are Tight ☒ ☐ Verify Failure Direction ☒ ☐

Verify line(s) installed correctly ☒ ☐ Verify local Display ☒ ☐

Device Installed as Per Design And Spec. ☒ ☐ Ensure Process Sensing/Impulse Lines Are Open ☒ ☐

Ensure Manifolds Are Placed Back Into Service ☒ ☐

Verify Fault (Open Loop) ☒ ☐

Calibration Check Results

Input % Input Output/mA Local Display

Upscale Downscale Upscale Downscale Upscale Downscale

0% -50 -50 4 4

25% 41.4 41.4 8 8

50% 132.8 132.8 12 12

75% 224.2 224.2 16 16

100% 315.6 315.6 20 20

Test Equipment

Manufacturer Model Serial # Calibration Date

Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:

Field Inspector: Danny Hengerer Signature: Date: 2019-04-21

CDN Rep.: Nick Prevost Signature: Date: 2019-04-21

Client Rep.: Kelly Samis Signature: Date: April 21, 2019



RECORD




Type:temperature

transmitterDate:

2019-04-21




RECOVERY EXCHANGER

OUTLET



Data Sheet:

Burnout













0% -50 -50 4 4

25% 41.4 41.4 8 8

50% 132.8 132.8 12 12

75% 224.2 224.2 16 16

100% 315.6 315.6 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD




Type:temperature

transmitterDate:

2019-04-21




RECOVERY EXCHANGER

OUTLET



Data Sheet:

Burnout













0% -50 -50 4 4

25% 41.4 41.4 8 8

50% 132.8 132.8 12 12

75% 224.2 224.2 16 16

100% 315.6 315.6 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD




Type:temperature

transmitterDate:

2019-04-21




RECOVERY EXCHANGER

OUTLET



Data Sheet:

Burnout













0% -50 -50 4 4

25% 41.4 41.4 8 8

50% 132.8 132.8 12 12

75% 224.2 224.2 16 16

100% 315.6 315.6 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD




Type:temperature

transmitterDate:

2019-04-21




RECOVERY EXCHANGER

OUTLET



Data Sheet:

Burnout













0% -50 -50 4 4

25% 41.4 41.4 8 8

50% 132.8 132.8 12 12

75% 224.2 224.2 16 16

100% 315.6 315.6 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD




Type:temperature

transmitterDate:

2019-04-21




RECOVERY EXCHANGER

OUTLET



Data Sheet:

Burnout













0% -50 -50 4 4

25% 41.4 41.4 8 8

50% 132.8 132.8 12 12

75% 224.2 224.2 16 16

100% 315.6 315.6 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD



Device Tag: FIT-5110-1 Type: flow transmitter Date: 2019-04-21


Model:2051CD2A02A1AS5K6M5P1Q4Q8


RECOVERY

EXCHANGER INLET


Instr. Range: - Calib. Range: 0-4736 (25) Display Range:

Data Sheet:

Burnout













0% 0 0 4 4

25% 6.25 6.25 8 8

50% 12.5 12.5 12 12

75% 18.75 18.75 16 16

100% 25 25 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD







RECOVERY

EXCHANGER INLET



Data Sheet:

Burnout













0% 0 0 4 4

25% 6.25 6.25 8 8

50% 12.5 12.5 12 12

75% 18.75 18.75 16 16

100% 25 25 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD







RECOVERY

EXCHANGER INLET



Data Sheet:

Burnout













0% 0 0 4 4

25% 6.25 6.25 8 8

50% 12.5 12.5 12 12

75% 18.75 18.75 16 16

100% 25 25 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD







RECOVERY

EXCHANGER INLET



Data Sheet:

Burnout













0% 0 0 4 4

25% 6.25 6.25 8 8

50% 12.5 12.5 12 12

75% 18.75 18.75 16 16

100% 25 25 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD







RECOVERY

EXCHANGER INLET



Data Sheet:

Burnout













0% 0 0 4 4

25% 6.25 6.25 8 8

50% 12.5 12.5 12 12

75% 18.75 18.75 16 16

100% 25 25 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:






RECORD





Model: 2051CD2A02A1AS5

K6M5P1Q4Q8


RECOVERY EXCHANGER

INLET



Data Sheet:

Burnout













0% 0 0 4 4

25% 6.25 6.25 8 8

50% 12.5 12.5 12 12

75% 18.75 18.75 16 16

100% 25 25 20 20

Test Equipment


Fluke 725 74750021 March 1, 2019

Fluke 721 2960033 March 4, 2019

Comments:




Documents

GHG Report Tourmaline Oil Gundy Creek Gas Plant Waste Heat