ALBERTA REMVUE ENGINE FUEL MANAGEMENT AND VENT GAS CAPTURE AGGREGATION PROJECT Greenhouse Gas Emissions Reduction Offset Project Plan For The Period: 1 January, 2013 – 31 December, 2020 FINAL REPORT, version 2.3 20 December, 2013 Prepared by: Blue Source Canada ULC (Project Proponent) Suite 700, 717-7 th Avenue SW Calgary, Alberta T2P 3R5 T: (403) 262-3026 F: (403) 269-3024 www.bluesourceCAN.com
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ALBERTA REMVUE ENGINE FUEL MANAGEMENT
AND VENT GAS CAPTURE AGGREGATION PROJECT
Greenhouse Gas Emissions Reduction
Offset Project Plan
For The Period: 1 January, 2013 – 31 December, 2020
FINAL REPORT, version 2.3
20 December, 2013
Prepared by: Blue Source Canada ULC (Project Proponent) Suite 700, 717-7
Contents Contents ......................................................................................................................................................... i
List of Figures ............................................................................................................................................... iii
List of Tables ................................................................................................................................................ iii
List of Abbreviations .................................................................................................................................... iv
1 Project Scope and Site Description ....................................................................................................... 1
1.1 Contact Information ...................................................................................................................... 3
TABLE 8: EFM DATA MONITORING PLAN .................................................................................................................... 33
TABLE 9: VGC DATA MONITORING PLAN ..................................................................................................................... 34
TABLE 10: CONTINGENT DATA MONITORING AND COLLECTION FOR ALL SOURCES .................................................. 36
The project title is: Alberta REMVue Engine Fuel Management and Vent Gas Capture Aggregation Project
The project’s purpose(s) and objective(s) are:
The project objective is two-fold: 1) To increase the fuel efficiency and thus reduce combustion emissions attributed to the operation of both lean burn and rich burn engines, and 2) To capture otherwise vented emissions from engine packing, casing, etc. and re-inject into a natural gas combustion engine. The greenhouse gas reductions will be achieved through the retrofit installation of various engine management technologies on existing or new engine units within Alberta. This can include engine modification in the form of air/fuel ratio (AFR) control, vent gas capture systems and other features to improve engine start performance such as improved spark plug design.
Date when the project began:
The earliest subproject began on 16 July, 2003 and is a result of actions taken on, or after, 1 January, 2002.
Credit start date: 1 January, 2013
Credit duration period: 1 January, 2013 to December 31, 2020
Expected lifetime of the project:
The technology lifetime of the REMVue Air/fuel Controllers and REMVue SlipStream vent gas capture systems will be equivalent to the lifetime of the engine or compressor package to which they are installed and can reasonably be expected to be in excess of 15-20 years. Specific to the REMVue EcoPlug, the expected lifetime can be in excess of two years; however plug replacements typically occur on an annual basis. Subprojects involving the substitution of standard spark plugs with EcoPlugs will be subject to plug performance and site maintenance practice.
Estimated emissions reductions:
The total project emission reductions from this project are estimated to be 188,527 tonnes of CO2e as follows:
The quantification protocol used is the Quantification Protocol for Engine Fuel management and Vent Gas Capture Projects (version 1.0, October 2009) (the “Protocol”) published by Alberta Environment (AENV).
Protocol(s) Justification: The project activities outlined herein are included in the scope of the protocol as they result in the implementation of an improved engine management system that results in the conversion of a rich burn engine to a lean burn engine, the improved combustion efficiency of new spark plugs, or the capture and commercial use of previously vented emissions from engine packing. These retrofits will reduce fuel consumption and vented emissions associated with day to day operations. These actions are considered beyond business as usual as increasing fuel efficiency of operations is not regulated by Alberta Environment and Sustainable Resource Development (ESRD) or by the Alberta Energy Regulator (AER). They are above and beyond current industry practice regarding engine operation and vented emissions.
Other Environmental Attributes:
This project is not generating any other environment credits (such as Renewable Energy Certificates (RECs)). There are no opportunities for potential double counting as this project is only registered with the AEOR.
Legal land description of the project or the unique latitude and longitude:
The subprojects are located in Alberta. Refer to the project registration package (included at time of project submission) for the subproject tracking form for detailed location information.
Ownership: Blue Source Canada is the aggregator and project proponent for this project. Via the agreements with each participating company (i.e. the owners of the technologies that have been installed), Blue Source is given authority to aggregate and register the project's Offset Credits. The ownership model varies with each participating company depending on the respective agreements. In some cases ownership is defined by the Direct Purchase agreement with transfer of title occurring at time of registration, while other agreements follow the Agency model, with title remaining with the subproject owner until time of sale. For each participating company, the respective agreements will be made available at time of verification to define ownership of all subprojects .
Reporting details: The first reporting period for the project will cover the period from 1 January, 2013 to 31 December, 2013. Subsequent reporting is expected to occur annually covering the duration of each calendar year.
Verification details: The verifier will be an independent third-party that meets the requirements outlined in the Specified Gas Emitters Regulation (SGER). An acceptable
verification standard (e.g. ISO14064-3) will be used and the verifier will be vetted to ensure technical competence with this project type.
Project activity & registration:
This project meets the requirements for offset eligibility as outlined in section 3.1 of the Technical Guidance for Offset Project Developers (version 4.0, February 2013). In particular: 1. The project occurs in AB: as outlined above;
2. The project results from actions not otherwise required by law and
beyond business as usual and sector common practices: Offsets being claimed under this project originate from voluntary actions. The project activities (i.e. engine fuel management and vent gas capture) do not occur at SGER regulated facilities and are not required by law. The project uses a government approved quantification protocol, which indicates that the activity is undertaken by less than 40% of the industry and is therefore not considered to be sector common practice;
3. The project results from actions taken on or after January 1, 2002: as
outlined above;
4. The project reductions/removals are real, demonstrable, quantifiable and verifiable: the project is creating real reductions that are not a result of shutdown, cessation of activity or drop in production levels. The emission reductions are demonstrable, quantifiable and verifiable as outlined in the remainder of this plan.
5. The project has clearly established ownership: The program participants
must have superior claim of ownership over any other person or company to the emissions reductions created by the subproject. Ownership will be demonstrated through confidential documents reviewed by Blue Source and made available to the verifier. Title to the offsets will be transferred to Blue Source from the program participants through a contractual agreement.
6. The project will be counted once for compliance purposes: The project
credits will be registered with the Alberta Emissions Offset Registry (AEOR) which tracks the creation, sale and retirement of credits. Credits created from the specified reduction activities have not been, and will not be, created, recorded or registered in more than one trading registry for the same time period.
1.1 Contact Information Project Participant (s) Contact Information
Apache Canada LTD. Steve Flesch Business Financial Advisor
Suite 2800, 421-7th Ave S.W. Calgary, Alberta Canada T2P 4K9
2.2 Project Participants and Sub-Projects Included At the time of registering this OPP, the project participants and sub-projects included in the Project are
as outlined in Table 1.
Table 1: Summary of project participants and sub-projects by type
2.4 Description of how the project will achieve GHG emission reductions/removals The ability of the aggregation project to achieve GHG emission reductions presents itself through the
application of the three technology types described in the introduction. It is feasible that for one engine,
all three technologies or any combination thereof could be installed and operational simultaneously.
Therefore any one engine could demonstrate the GHG emission reductions resulting from the
application of any combination of the three technologies.
2.4.1 Technology 1a: REMVue Air/fuel Ratio Controller
Without the application of an EFM
system, the engine will continue to
operate under a rich burn
combustion configuration. GHG
emissions from a rich burn engine
arise from the larger volume of fuel
required to obtain combustion at
stoichiometric conditions.
Additional criteria air contaminants (CACs) including carbon monoxide (CO) and Volatile Organic
Compounds (VOCs) arise from incomplete combustion. In addition, thermal dissociation and
subsequent reaction of nitrogen (N2) and oxygen (O2) yield oxides of Nitrogen (NOX).
To facilitate a leaner combustion and reduce the formation of unwanted products, the REMVue AFR
system installation includes the following monitoring and control equipment as illustrated in Figure 4.
Turbo Charger Waste Gate Control Actuator/Positioner – which control the mass of air into the
unit;
Local Operator Interface display – which provides feedback on the unit's performance to the
unit operator;
Micromotion mass flow meter – which measures the fuel consumed by the unit;
Main fuel control valve – which controls the mass of fuel into the unit;
Air manifold pressure and temperature transmitters – for system control purposes; and
Magnetic speed sensor – measures engine speed for system control purposes.
3 Inventory of Sources and Sinks The Protocol contains a list of baseline and project sources and sinks (SSs) that were deemed applicable for projects developed according to the
protocol. The SSs for the Project are identified in Figure 7, below.
Included Sources/Sinks
P1 Fuel Extraction & Processing
P2 Fuel Delivery
P3 Facility Operation
P4 Unit Operation
P6 Flaring of Process Emissions
P5b Venting of Emissions Captured in
the Project
P5a Venting of Process Emissions
P7 Electricity Usage
P8 Development of Site
P9 Building Equipment
P10 Transportation of Equipment
P11 Construction on Site
P12 Testing of Equipment
P13 Site Decommissioning
Figure 7: Simplified PFD of subproject technologies, post-project. Diamond shapes represent sources specific to the REMVue SlipStream subproject
3.1 Quantification of estimated GHG emissions/removals The following equations serve as the basis for calculating the emission reductions from the comparison
of the baseline and project conditions as per the Protocol:
Emissions Baseline= sum of the emissions under the baseline condition = Emissions Fuel Extraction / Processing = emissions under SS B1 Fuel Extraction and Processing
Emissions Unit Operation = emissions under SS B4 Unit Operation
Emissions Venting of Emissions Captured in Project = emissions under SS B5b Venting of Emissions Captured in Project
Emissions Project = sum of the emissions under the project condition =
Emissions Fuel Extraction / Processing = emissions under SS P1 Fuel Extraction and Processing
Emissions Unit Operation = emissions under SS P4 Unit Operation
Emissions Capture of Vent Gases = emissions under SS P5b Capture of Vent Gases
3.1.1 Justification for excluding sources and sinks
As stated in the Protocol not all parameters are applicable to all EFM or VGC systems. Those sources and
sinks (SSs) that are not applicable will be excluded as the input variables will be zeroes. As such, the
project developer can exclude sources and sinks that are not applicable to their project with reasonable
justification.
The following SSs have been excluded from quantification for subprojects employing EFM systems:
Emissions under SS (B5b) Venting of Emissions Captured in Project
Emissions under SS (P5b) Capture of Vent Gases
These SSs have been excluded from Technology 1 quantification as there is no capture of vent gases for
subprojects employing EFM systems such as the REMVue AFR controller. However, for quantification of
VGC subprojects these two sources will be included.
3.1.2 Quantification of Source and Sinks
The general methods of quantification (as listed in the Protocol) for the required greenhouse gas
calculations are as follows. Table 5 includes the emission factors relevant to the Project.
SS B1/P1 Fuel Extraction and Processing– The fuel avoided from the implementation of the EFM
technology like REMVue AFR or VGC system such as Slipstream would have otherwise been extracted
and processed in the baseline configuration. Note that this value is obtained from SS B4 and is equal to
the metered fuel consumption in the project condition multiplied by the Fractional Change in fuel
Table 6: Projection Based Baseline Identification (Alberta Environment, October 2009)
Subproject Technology
Baseline Scenario Justification
Technology 1: EFM
Assessment of the baseline GHG emissions from unit / engine operation using a model to project fuel consumption and the GHG intensity of unit operation into the future. This could include a projection of the GHG intensity based on past trends or expected future trends.
Dynamic. This approach is applicable for determining emissions from fuel consumption given that appropriate models exist to model the change in fuel consumption from the project to the baseline scenarios. Further, unlike the other baseline options this approach uses site-specific data of unit fuel consumption at different RPMs and loads obtained from direct measurement.
Technology
2: VGC
Assessment of baseline GHG
emissions from venting using a model
to project the quantity and
composition of gases vented into the
future.
Dynamic. This approach is applicable for quantifying the GHG emissions from vent gas capture given that the quantity and composition of gases captured and combusted in the project condition can be used to estimate emissions in the baseline. Further, unlike the other baseline options this approach is based on direct measurement of the characteristics of vent gases that would have been emitted in the absence of the project.
For REMVue AFR and EcoPlug subproject applications, the baseline would be the continued operation of
the engine under original engine specifications as designated by the manufacture.
For the REMVue Slipstream there are two possible baseline scenarios:
1) The vented source gas is not conserved or flared;
2) The vented source gas is combusted in a flare or incinerator as stipulated by ERCB Directive
D060.
4.1 Functional Equivalence Functional equivalence is introduced through the desired output of the technology. For both
subprojects, the desired objective is to run the engine to power a compressor. The make/model,
runtime, or level of output of the compressor does not change from the implementation of the
subproject activity.
5 QUANTIFICATION PLAN This project quantifies GHG emission reductions according the Protocol. Descriptions of the project
specific details are provided in Section 2.6 “Subproject technologies, products, services and the
5.2 Project Emissions Project emissions from SS P1 Fuel Extraction and Processing, SS P4 Unit Operation and SS P5b Capture of
Vent Gases have all been quantified under their respective baseline equivalent SS.
5.3 Determination of Brake Specific Fuel Consumption The GHG emission reduction assertion is based upon the determination of the engine’s brake specific
fuel consumption at the operating load and RPM prior to the installation of the REMVue AFR controller,
and the reduction that occurs in brake specific fuel consumption (BSFC) at the same load and RPM after
the engine is retrofit. The use of BSFC to analyze engine fuel performance allows for the aggregation of
the AFR installations independent of engine type and size.
Appendix C in the protocol provides guidance on the calculation of BSFC. For a specified engine speed
and load:
)
) (7)
The Protocol outlines three methodologies that can be used for the majority of projects, based upon
data availability:
1) The Simple Method;
2) The Advanced Method;
3) The Flexibility Mechanism.
5.3.1 The Simple Method
For engines where the measured load changes <5% between pre and post audits and the project
condition, the simple method can be employed. This involves the determination of BSFC at three
different RPMs and one load as it is assumed that the fractional change in BSFC is dependent upon RPM
only. In this method, linear interpolation or least squares best fit of the audit data can be followed.
If the load noticeably changes >5%, then normalization of the pre-audit BSFC and recalculation of the
post-audit BSFC is required as outlined in the Protocol Appendix C-1.
5.3.2 The Advanced Method
Rarely is load expected to change <5% throughout the duration of the engine life. Therefore, in most
cases the advanced method is required. To apply this methodology, three BSFC values at three distinct
RPMs should be collected in the pre and post audit to obtain two full load maps of BSFC vs. Load before
and after the engine modification. Each three point curve theoretically could then be fit with a second
6.1 Technology 1/1b: REMVue AFR/EcoPlug Table 8: EFM Data monitoring plan
Source/sink identifier or name:
B1 Fuel Extraction and Processing
B4 Unit Operation B4 Unit Operation
Data parameter: Volume of Natural Gas Combusted for B4
Total Fuel Consumption in Project Condition
Fractional Change in Fuel Consumption from Baseline to Project due to Implementation of an Air-Fuel Ratio Controller
Estimation, modeling, measurement or calculation approaches:
direct metering direct metering and monthly aggregation of values
Estimated
Data unit: e3m3 e3m3 %
Source/origin: Direct metering of fuel consumption of unit. Note that this value is obtained from B4 and is equal to the metered fuel consumption in the project condition multiplied by the Fractional Change in fuel consumption from the baseline to the project.
Calculated based on the continuous measurement of mass flow rate of fuel into the engine in the Project Condition. In project configurations where vent gases are captured and fed back into the engine for supplemental fuel, the total fuel consumption is the sum of the main fuel gas stream and the supplemental vent gas fuel, expressed as an energy equivalent quantity of the primary fuel (e.g. natural gas).
Fractional Change in fuel consumption from the baseline to the project condition is calculated based on measured BSFC values from pre and post installation, corrected for actual project loads and engine RPMs on a monthly basis. Fractional Change = (BSFC Pre-Audit – BSFC Post-Audit)/ BSFC Post-Audit. Refer to Appendix C for a step by step procedure to determine the fractional change in fuel consumption. Refer to Table C.3 in Appendix C (page 62) for a summary of monitoring requirements in the project
Data unit: e3m3 Kg/month Kg/m3 Kg/month Kg/m3 GJ/m3 GJ/m3
Source/origin: Calculated based on the energy content, composition and mass flow rate of vent gas input into the engine to determine the equivalent quantity of fuel displaced.
Quantity being Calculated. This quantity represents the incremental fuel savings from the use of a waste vent gas stream as a supplemental fuel (these fuel savings would be in addition to the fuel savings from the implementation of an air-fuel ratio controller).
Continuous measurement of the fuel flow rate on a mass basis for the primary fuel meter. Note that the primary fuel meter will be the only fuel meter for project configurations that do not capture vent gas.
Frequency of metering is highest level possible. For the purposes of this protocol, continuous monitoring means collecting one data point at least every fifteen minutes
Calculated based on the molar composition of the fuel gas at 15°C and 101.3kPa, the standard reference conditions used by the fuel gas
Continuous measurement of the vent gas flow rate into the unit on a mass basis in the project condition.
Measured by a third party gas analysis or calculated based on gas composition. See Appendix C-3 for further detail.
Monitoring frequency:
Continuous Continuous Annual Fuel Gas Sampling
Continuous metering and monthly aggregation of values
Uncertainty: n/a Stated Meter Manufacturer’s Tolerance
Stated Lab Analysis’ Tolerance
Stated Meter Manufacturer’s Tolerance
Stated Lab Analysis’ Tolerance
Stated Lab Analysis’ Tolerance
Stated Lab Analysis’ Tolerance
Provide the details for any deviations for the protocol including the justification and rationale:
n/a n/a n/a n/a n/a n/a n/a
6.3 Contingent Data Monitoring For data where measurements are unavailable, the data monitoring will follow the contingent procedures as outlined in Appendix B of the
Protocol and pasted below for ease of reference:
Table 10: Contingent Data Monitoring and Collection for all sources
Project/ Baseline
SS Parameter Unit Measurement/Estimation Contingency Method Frequency Justification
B4 Unit Operation
Total Fuel Consumption in project Condition/Fuel Consumption
m3 Measurement Interpolation of previous and following measurements
Continuous metering and monthly average of values
Frequency of metering is highest level possible
P6 Flaring of Process Emissions
Volume of Fuel used to Supplement Flaring Of process Emissions
m3 Estimated Calculated based on flare design specifications (flare tip diameter and flare stack diameter), flow rate of gases flared, typical heat value of gas stream
Monthly Method represents reasonable diligence when more accurate method is unachievable. If metered data is unavailable project
SS Parameter Unit Measurement/Estimation Contingency Method Frequency Justification
sent to flare and heat value of fuel used to supplement flaring. Fuel Gas usage is the sum of pilot gas, purge gas and makeup gas.
proponents should refer to the Fuel Gas Best Management Practices series of documents Module 4 Efficient Use of Fuel Gas for Flaring Operations for reference tables and formulas to estimate typical purge gas, pilot gas and makeup gas usage for flares.
Volume of Process Emissions Flared in Project / Volume Flared Gases
m3 Estimation Estimated based on facility operating records (upsets) and historical monthly flared volumes. If metered data and facility records are unavailable project proponents should use the highest monthly volume of gas flared in the past year as a conservative value.
Monthly Reconciliation
Method represents reasonable diligence when more accurate method is unachievable.
Volume of Each Hydrocarbon Contained in the Process Emissions Stream/ %CnHm
% Volume
Estimation Estimation of gas stream composition based on typical industry compositions at relevant upstream oil and gas facilities.
Annual Method represents reasonable diligence when more accurate method is unachievable.
SS Parameter Unit Measurement/Estimation Contingency Method Frequency Justification
B6 Flaring of Process Emissions
Volume of Fuel Used to Supplement Flaring of Process Emissions / Vol. Flare Fuel
m3 Estimation For conservativeness, project proponents may assume that no fuel is required to supplement flaring.
Annual Represents a conservative approach to quantification of baseline emissions
Mass of Process Emissions Combusted in Unit in Project / Mass Captured Gases
kg Estimation Interpolation of previous and following measurements. Project proponents should provide records of unit operating hours to ensure that process emissions were being used as supplemental fuel.
Monthly Reconciliation
Method represents reasonable diligence when more accurate method is unachievable.
Density of Process Emissions in Project Condition / Density Captured Gases
Kg/m3 Estimation Estimation of gas stream composition based on typical industry compositions at relevant upstream oil and gas facilities.
Annual Method represents reasonable diligence when more accurate method is unachievable.
% Volume of Each Hydrocarbon Contained in the Process
% Volume
Estimation Estimation of gas stream composition based on typical industry compositions at relevant upstream oil and gas
Annual Method represents reasonable diligence when more accurate method is unachievable.
7 DATA INFORMATION MANAGEMENT SYSTEM AND RECORDS The Information Management System (IMS) created for this aggregation is intended to direct and collect
GHG data monitoring activities for both the project and baseline data monitoring requirements. The
system outlined below will describe the robustness, transparency and automation that have been built
to reflect a reasonable level of assurance with respect to the following objectives outlined in Section 5.1
of the Technical Guidance for Offset Project Developers, version 4.0, February 2013:
Completeness
Accuracy
Validity
Restricted Access
7.1 Data Control Controls exist throughout the data management system, but are essential whenever there is a transfer or exchange of data or information. Examples of data controls used consistently throughout the aggregation include:
passwords on computers; read access requirements on files; Management review of reports.
7.2 Data Management Data management procedures will vary depending on the type and format of data received. Manually
sourced data will be scanned and electronically saved to an identified folder within the project
information file. Manual data will be checked for completeness, reasonableness and transcription errors
with any findings identified and discussed with the project participant.
Other data is sourced directly from project participants’ online SCADA systems. Information obtained
from these systems are often directly downloaded into an excel file and copied into the Blue Source
excel based quantification calculator and Map Modeller input files. Copies of the downloaded content
will be saved in a unique project folder under the date it was downloaded from the online system.
All data gathered for the project will be stored at Blue Source for a period of seven years after the end of
the project crediting period.
Figure 8 on the following page illustrates the data flow and origin from project participants and third
07-19-034-25W4 Three Hills 07-19 Field Booster PN21238 L7042GSI
Project Participant Company Name
Legal Land Location Facility Unique Spartan
Identifier Waukesha VHP Series
Engine Model
11-18-066-10W6 Wapiti 11-18 PN25467 F3521GSI
04-23-066-08W6 Wapiti South Block Comp Stn C-330 PN20129/RM-01838-
AA P9390GSI
04-23-066-08W6 Wapiti South Block Comp Stn C-331 PN20130/RM-13213-
AA P9390GSI
Talisman Energy Inc. LSD Confirmation Required Pass Creek 11229 L7042GSI LSD Confirmation Required Tony Creek 11231 L7042GSI LSD Confirmation Required Saxon 11232 P9390GSI
03-29-062-20 W5 Bigstone 18303 P9390GSI
14-20-56-23W5 Wild River 27247 F3521GSI Table 13: Subproject Tracking List – Project Type: VGC System Type: REMVue SlipStream
Project Participant
Company Name Legal Land Location Facility
Unique Spartan Identifier
Engine Make Engine Model
Centrica Energy Canada
09-08-016-04W4 Medicine Hat ID Confirmation Waukesha 3524 GSI
09-08-016-04W4 Medicine Hat ID Confirmation Waukesha 3524 GSI
09-20-016-04W4 Medicine Hat RM-15902-AB Waukesha 3524 GSI
09-20-016-04W4 Medicine Hat ID Confirmation Waukesha 3524 GSI
09-28-015-04W4 Medicine Hat ID Confirmation Waukesha 3524 GSI
09-28-016-04W4 Medicine Hat ID Confirmation Waukesha 3524 GSI
13-33-051-08W5 Medicine Hat, Project 3
ID Confirmation Waukesha 7042 GSI
13-33-051-08W5 Medicine Hat, Project 3
ID Confirmation Waukesha 7042 GSI LSD Confirmation Required Ferrier ID Confirmation White Superior 8GTL-825 LSD Confirmation Required Gilby ID Confirmation Waukesha 9390 GSI LSD Confirmation Required Gilby Field Office ID Confirmation Waukesha 9390 GSI LSD Confirmation Required Gilby Field Office ID Confirmation Waukesha 9390 GSI LSD Confirmation Required Ferrier ID Confirmation White Superior 8GTL-825 LSD Confirmation Required Ferrier ID Confirmation White Superior 8GTL-825
Appendix E – Confidential Methodology: The Master Map Made available to Third- Party Verifiers