Developed by Blue Source Canada for the Pacific Carbon Trust
March 2011
Version 1.1

Table of Contents
1.
2.
Project Scope and Description .......................................................................... 2
Module Scope and Description ........................................................................ 2
2.1. Module Approach ............................................................................................. 3
2.2. Module Applicability ......................................................................................... 3
2.3. Module Flexibility ............................................................................................. 4
3.
4.
Project Reporting .............................................................................................. 5
Glossary of New Terms ..................................................................................... 8
5. Quantification Development and Justification ................................................. 8
5.1. Identification of the SSRs in the Project Condition .......................................... 8
5.2. Identification of the Baseline .......................................................................... 10
5.3. Identification of SSRs in the Baseline Condition ............................................. 11
5.4. Selection of Relevant Project and Baseline SSRs ............................................ 12
5.5. Quantification of Reductions, Removals and Reversals of Relevant SSRs ..... 14
5.5.1. Quantification Approaches ....................................................................... 14
5.5.2. Accuracy .................................................................................................... 19
List of Appendices
Appendix A: Flexibility Mechanisms
Appendix B: Pump Displacement Factor
Appendix C: Contingent Data Approaches
List of Tables
Table 3.1: Key Data Project Reporting Table ...................................................................... 7
Table 5.1: Project SSRs ........................................................................................................ 9
Table 5.2: Baseline SSRs .................................................................................................... 11
Table 5.3: Comparison of SSRs .......................................................................................... 13
Table 5.4: Quantification Procedures ............................................................................... 15
List of Figures
Figure 1.1: Possible Pathways Pump Retrofits ................................................................... 2
Figure 2.1: Process Flow Diagram for Project Condition .................................................... 5
Figure 2.2: Process Flow Diagram for Baseline Condition .................................................. 5
Figure 5.1: Project Element Lifecycle Chart ........................................................................ 9
Figure 5.2: Baseline Element Lifecycle Chart .................................................................... 11
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Page 2 |
This module is an adaptation of the Alberta Offset System Draft Quantification Protocol for Pump System Conversion to Reduce Greenhouse Gas Emissions (March 2009)
1
. It is meant to be used in conjunction with the Meta-Protocol Introduction and is not a standalone document.
This quantification methodology is written for the gas and/or oil operator or any operator in the oil and gas industry where natural gas or electricity is used to power chemical injection pumps. The opportunity for generating carbon offsets under this module arises from the direct reduction of greenhouse gas emissions resulting from converting high GHG intensive pumps to low/non-emitting pumps or low GHG intensive pumps to non-emitting pumps. In this module, the project developer will install low/non-emitting pumps, or update or retrofit high/low GHG pumps. Figure 1.1 shows types of pump categorized as high, low, or non-emitting pumps. The arrows represent possible retrofit scenarios.
Figure 1.1: Possible Pathways Pump Retrofits
GHG Intensity
High
High GHG Pumps
•
Natural gas
Low GHG Pumps
•
Compressed air
•
Electricity
•
Natural gas with
Vent Gas Recapture
Non-Emitting Pumps
•
Renewable or grid electricity
•
Natural gas with
100% vent gas recapture
Zero
This module serves to quantify reductions resulting from converting high GHG intensive pumps to low/non-emitting GHG intensive pumps, or low GHG intensive pumps to nonemitting pumps. Replacement of end-of-life pumps and new installations are also
1 http://carbonoffsetsolutions.climatechangecentral.com/files/microsites/OffsetProtocols/ProtocolReview
Process/5thCycleProtocolDevelopment/Pumping%20Systems%20Protocol-Draftv2%20PostReview.pdf

considered in the scope of this methodology. The intent of this inclusion is to stimulate project developers to buy low/non-emitting pumps rather than high GHG pumps. A process flow diagram for a typical project converting high/low GHG intensive pumps to low/non-emitting pumps is shown in Figure 2.1.
2.1.
The baseline condition has been identified as the use of high or low GHG intensive pump systems at a facility. High GHG intensive pump systems are powered by pressurized natural gas sourced from the facility fuel supply (“Fuel gas”). Low GHG intensive pumps are powered by electricity, compressed air, or natural gas with vent gas recapture.
Baseline emissions for high GHG intensive pumps stem from vented natural gas used to operate pneumatic pumps, whereas baseline emissions from low GHG intensive pumps stem from electricity consumption. Baseline emissions are site-specific, depending on the type of pump and its operating conditions. As such, a projection-based approach is the most accurate method of quantifying baseline emissions.
The general module approach requires the calculation of greenhouse gas emissions using manufacturer technical specifications for high GHG intensive pumps, low GHG intensive pumps, and non-emitting pumps, and metered quantities in the project condition. The manufacturer technical specifications are used to determine a pumpspecific Pump Displacement Factor (PDF). Examples of how to determine PDFs are shown in Appendix A. Metered quantities of fluid displaced in the project condition are applied to pump-specific PDFs to estimate baseline emissions. A process flow diagram for the baseline condition is shown in Figure 2.2.
The project condition has been identified as the use of low or non-emitting pumps at a facility after the conversion. Low GHG intensive pump systems are powered with offgrid electricity, compressed air, or natural gas with vent gas recapture. Non-emitting pumps use renewable electricity (e.g. solar) or grid electricity to power pumps, or have
100% vent gas recapture. Project emissions arise from the use of electricity to operate the pumps, if non-renewable sources of electricity are used. Project emissions are calculated based on the volume of fluid injected and the electricity consumption rate for the electric pump, as determined from the manufacturer’s PDF. For the majority of project configurations, the project emissions will be zero as solar powered pumps are commonly used to replace pneumatic pumps.
2.2.
To demonstrate that a project meets the requirements under this module, the project developer must supply sufficient evidence to demonstrate that:
Page 3 |

1.
The conversion to low/non-emitting pumps displaces the same type of fluid and provides the same level of services (i.e. functional equivalence) as the high/low
GHG intensive pumps, as demonstrated by unit operational performance data, and/or facility process flow diagrams and/or other equipment technical specifications.
Due to higher operational precision of low/non-emitting pumps, less fluid may be injected in the project scenario than the volume of fluid that would have been injected in the baseline scenario. Although functional equivalence is not maintained between the project and the baseline condition, this situation results in a conservative estimate of baseline emissions and is therefore permissible.
2.
The project is applicable to retrofits or end-of-life replacements of high/low GHG intensive pumps to low/non-emitting pumps, or to facilities originally designed to use low/non-emitting GHG intensive pumps. For more detail on determining end of life, see Appendix B in the Meta-Protocol Introduction. Pump conversions may be demonstrated by facility process flow diagrams and/or equipment purchase records, work orders, invoices or other vendor/third party documentation.
2.3.
The module is applicable to any kind of pump conversion program intended to reduce/eliminate greenhouse gas emissions. Given the diversity of pumps operated in the oil and gas industry, the following flexibility mechanism has been put in place:
1.
The baseline for end-of-life replacements and new installations is a gas-driven pneumatic pump which provides an equal level of service and has the lowest bleed rate available. Flexibility is given to project proponents that wish to determine a more accurate baseline pump, based on industry common practice. It is up to project proponents to justify that the use of this flexibility mechanism results in a higher degree of accuracy than the method specified in the protocol.
Page 4 |

Figure 2.1: Process Flow Diagram for Project Condition
P3a Grid
Electricity
Generation
P3b Grid
Transmission
Losses
P4 Fluid
Production/
Processing
P2
Fuel
Delivery
P7 Electricity
Generation
(On-Site)
P5
Low/Non-
Emitting Pump
P1 Fuel
Extraction/
Processing
P6
Downstream
Fluid Processing
Figure 2.2: Process Flow Diagram for Baseline Condition
B3a Grid
Electricity
Generation
B3b Grid
Transmission
Losses
B4 Fluid
Production/
Processing
B2
Fuel
Delivery
B7 Electricity
Generation
(On-Site)
B5
High/Low GHG
Intensive Pump
B1 Fuel
Extraction/
Processing
B6
Downstream
Fluid Processing
P8
Vented
Emissions
Consumption
B8
Vented
Emissions
Consumption
Page 5 |

The project reporting table provided below is meant to assist validators and verifiers in identifying key project data monitoring requirements. These are the minimum monitoring requirements necessary to quantify emissions. In no way does Table 3.1 purport to provide a complete summary of data requirements. It is the responsibility of project proponents to correctly quantify emissions reductions using the methods set out in this module.
In addition, the following checklist serves as a summary of module applicability requirements that may be reviewed to ensure that each project meets the requirements of this module. It is the responsibility of project proponents to correctly assess applicability requirements as laid out in this module.
Applicability Checklist
The new pump installed as a retrofit displaces the same type of fluid and provides an equal level of service as the original high GHG intensive pump.
End of life replacements must demonstrate a clear intent to increase environmental performance.
Page 6 |

Table 3.1: Key Data Project Reporting Table
Pump System Conversion Reporting Table
Date of Fuel
Gas Analysis
-
Month
-
January
Basin/Site Location of Fuel Gas Analysis
-
Installation ID:
Yearly Monitoring Requirements
CH
4
Content of Gas
%
CO
2
Content of Gas
%
Baseline
PDF m
3
gas/ m
3
fluid
Monthly Monitoring Requirements
Volume Fluid Displaced m
3 fluid
Emission Reductions kg CO
2e
Project
PDF m
3
fluid/ kWh
February
March
April
May
June
July
August
September
October
November
December
Page 7 |

High GHG Intensive Pump
Low GHG Intensive Pump
Non-Emitting Pump
Pump
Pump Displacement Factor
Any pump that uses pressurized natural gas as a power source to displace a fluid. This natural gas is subsequently vented to the atmosphere.
Any pump that uses electricity or compressed air as power source to displace a fluid. Electricity may be from the grid or generated internally. The pump may also use pressurized natural gas a power source with partial vent gas capture.
Any pump that is powered by renewable electricity
(i.e. solar, wind) or uses natural gas and recaptures
100% of the vented methane.
A pump is an apparatus used to move or displace fluids, such as gases, liquids or slurries.
The Pump Displacement Factor (PDF) measures the ratio of the amount of energy required to displace a fluid by pump to the amount of fluid displaced. For example, a PDF could be given in units of m
3 fluid/kWh or m
3 natural gas/m
3
fluid.
A pump and accessories such as power source, cables, etc.
Pump System
5.1.
Identification of the SSRs in the Project Condition
SSRs were identified for the project by reviewing the relevant process flow diagrams pertaining to the operation of natural gas processing facilities. This process confirmed that the SSRs in the process flow diagrams covered the full scope of eligible project activities under the methodology.
Based on the process diagrams provided in
Page
8
|

Figure 2.1, the project’s SSRs were organized into lifecycle categories in Figure 5.1,
Description of each of the SSRs and their classification as controlled, related or affected are provided in Table 5.1. Note that SSRs previously defined in Meta-Protocol
Introduction are excluded from Figure 5.1 and Table 5.1 for brevity.
Figure 5.1: Project Element Lifecycle Chart
Upstream SSRs During Project
P4 Fluid
Production/
Processing
Upstream SSRs
Before Project
SSRs During Project
P7 Electricity
Generation
(On-Site)
P8
Vented
Emissions
P5 Low/ Nonemitting Pump
Downstream SSRs During Project
Downstream SSRs
After Project
P6
Downstream
Fluid Processing
Table 5.1: Project SSRs
1. SSR 2. Description
Upstream SSRs During Project Operation
P4 Fluid Each of the fluids displaced throughout the project will need to be
Production/
Processing sourced and processed. Types and quantities of fluids used would need to be tracked. This will allow for the calculation of greenhouse gas emissions from the various processes involved in the production, refinement, and storage of the fluids.
Onsite SSRs During Project Operation
P7 Electricity
Generation
(On-Site)
Electricity may be required for operating the pumps or repressurizing the captured fuel gas. This power is sourced from internal generation. Quantity and source of the power are the important characteristics to be tracked as they directly relate to the quantity of greenhouse gas emissions.
P8 Vented
Emissions
Some pump systems use natural gas from the facility’s fuel supply.
Once the natural gas has powered the pump, it is left to vent to the atmosphere. Vented emissions in the project can be captured and reintroduced to the pipe network. Quantity and gas composition of
3.Controlled,
Related, or
Affected
Related
Controlled
Controlled
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|

1. SSR 2. Description the natural gas are important characteristics to be tracked as they directly relate to the quantity of greenhouse gas emissions avoided.
The low/non-emitting pump system and accessories such as power
P5 Low/Non-
Emitting Pump supply and assembly need to be manufactured by a specialized company. Quantity and source of the power are the important characteristics to be tracked as they directly relate to the quantity of greenhouse gas emissions.
Downstream SSRs During Project Operation
P6
Downstream
Fluid
Processing
Each of the displaced fluids throughout the project may need to be processed downstream. Types and quantities of fluids used would need to be tracked. This will allow for the calculation of greenhouse gas emissions from the various processes involved in the production, refinement, and storage of the fluids downstream.
Other
N/A
3.Controlled,
Related, or
Affected
Related
Related
5.2.
The type and volume of fluid displaced in the baseline is assumed to be the same as in the project condition as required by the operation of the facility. As such, the pump conversion is merely a change in the driving force that provides the required energy to pump the fluid. This allows functional equivalence to be established between the project and baseline condition. However, due to higher operational precision of low/non-emitting pumps, less fluid may be injected in the project scenario than the volume of fluid that would have been injected in the baseline scenario. Although functional equivalence is not maintained between the project and the baseline condition, this situation results in a conservative estimate of baseline emissions and is therefore permissible.
The protocol relies on manufacturer technical specifications combined with site-specific volumes of fluid purchased to establish the baseline. PDFs are established using manufacturer’s technical specifications to provide an accurate estimation.
The baseline for the operation of high/low GHG intensive pumps is the continued use of the existing high/low GHG intensive pump (e.g. pneumatic pump). Once the existing pump reaches the end of its useful life (see Meta-Protocol Introduction, Appendix B), the baseline is established using the procedure for end-of-life replacement and new facilities.
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10
|

The baseline for end of life replacements and new facilities is the equivalent gas pump which would provide an equal level of service to the project pump and that has the lowest bleed rate available.
2
5.3.
The baseline condition is defined, including the relevant SSRs and processes, as shown in
Figure 2.2. Table 5.2 gives a description of SSRs. Again, SSRs previously defined are excluded from Figure 5.2 and Table 5.2.
Figure 5.2: Baseline Element Lifecycle Chart
Upstream SSRs During Baseline
B4 Fluid
Production/
Processing
Upstream SSR
Before Baseline
SSRs During Baseline
B7 Electricity
Generation
(On-Site)
B8
Vented
Emissions
B5
High/Low GHG
Intensive Pump
Downstream SSRs During Baseline
Downstream SSR
After Baseline
B6
Downstream
Fluid Processing
Table 5.2: Baseline SSRs
1. SSR 2. Description 3.Controlled,
Related, or
Affected
Upstream SSRs During Baseline Operation
B4 Fluid Each of the fluids displaced throughout the project will need to be
Production/
Processing sourced and processed. Types and quantities of fluids used would need to be tracked. This will allow for the calculation of greenhouse gas emissions from the various processes involved in the
Related
2
According to Efficient Use of Fuel Gas in Chemical Injection Pumps by the Canadian Association of
Petroleum Producers, pneumatic fuel gas-driven pumps are the most commonly used in the oil and gas industry.
Page
11
|

1. SSR 2. Description
Generation
(On-Site) production, refinement, and storage of the fluids.
Onsite SSRs During Baseline Operation
Electricity may be required for operating the pumps or re-
B7 Electricity pressurizing the captured fuel gas. This power is sourced from internal generation. Quantity and source of the power are the important characteristics to be tracked as they directly relate to the quantity of greenhouse gas emissions.
B8 Vented
Emissions
Some pump systems use natural gas from the facility’s fuel supply.
Once the natural gas has powered the pump, it is left to vent to the atmosphere. Vented emissions in the project can be captured and reintroduced to the pipe network. Quantity and gas composition of the natural gas are important characteristics to be tracked as they directly relate to the quantity of greenhouse gas emissions avoided.
The high/low GHG intensive pump system and accessories such as power supply and assembly need to be manufactured by a B5 High/Low
GHG Intensive
Pump specialized company. Quantity and source of the power are the important characteristics to be tracked as they directly relate to the quantity of greenhouse gas emissions.
Downstream SSRs During Baseline Operation
B6 Each of the displaced fluids throughout the project may need to be
Downstream
Fluid
Processing processed downstream. Types and quantities of fluids used would need to be tracked. This will allow for the calculation of greenhouse gas emissions from the various processes involved in the production, refinement, and storage of the fluids downstream.
Other
N/A
3.Controlled,
Related, or
Affected
Controlled
Controlled
Related
Related
5.4.
Each of the SSRs from the project and baseline condition were compared and evaluated as to their relevancy in quantification of greenhouse gas emissions and reductions using
ISO 14064-2:2006. SSRs were identified as controlled, related or affected and included or excluded for quantification. The justification for the exclusion or conditions upon which SSRs may be excluded is provided in Table 5.3 below.
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12
|

Table 5.3: Comparison of SSRs
1. Identified SSR
2. Baseline
(C, R, A)
3. Project
(C, R, A)
4. Include or
Exclude from
Quantification
5. Justification for Exclusion
Upstream SSRs
P4 Fluid
Production/Processing
N/A Related Excluded
B4 Fluid
Production/Processing
Related N/A Excluded
Excluded as fluid production/processing is not impacted by the implementation of the project and as such the baseline and the project conditions will be functionally equivalent.
Onsite SSRs
P7 Electricity
Generation (On-Site)
B7 Electricity
Generation (On-Site)
P8 Vented Emissions
B8 Vented Emissions
Downstream SSRs
N/A
Related
N/A
Controlled
Related
N/A
Controlled
N/A
Included
Included
Included
Included
N/A
N/A
N/A
N/A
P6 Downstream Fluid
Processing
B6 Downstream Fluid
Processing
N/A
Related
Related
N/A
Excluded
Excluded
Excluded as downstream fluid processing is not impacted by the implementation of the project and as such the baseline and the project conditions will be functionally equivalent.
Other
P5 Low/Non-emitting
Pump
B5 High/Low GHG
Intensive Pump
N/A
Related
Related
N/A
Excluded
Excluded
Emissions from the manufacture of low/no GHG intensive pump are not material given the long project life and the minimal time required for construction of pumps and accessories.
Emissions from the manufacture from high GHG intensive pump are not material given the long project life and the minimal time required for construction of pumps and accessories.
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|

5.5.
5.5.1.
Quantification Approaches
Quantification of the reductions, removals and reversals of relevant SSRs for each of the greenhouse gases will be completed using the methodologies outlined in Table 5.4, below. These calculation methodologies serve to complete the following three equations for calculating the emission reductions from the comparison of the baseline and project conditions.
The general approach is to calculate the offsets as follows:
Emission Reduction = Emissions
Baseline
– Emissions
Project
Emissions
Project
= Emissions
Elec Gen
+ Emissions
Vented Emissions
Emissions
Baseline
= Emissions
Elec Gen
+ Emissions
Vented Emissions
Where:
Emissions
Baseline
= sum of the emissions under the baseline condition
Emissions
Elec Gen
= emissions under SSR B7 Electricity Generation (On-Site)
Emissions
Vented Emissions
= emissions under SSR B8 Vented Emissions
Emissions
Project
= sum of the emissions under the project condition
Emissions
Elec Gen
= emissions under SSR P7 Electricity Generation (On-Site)
Emissions
Vented Emissions
= emissions under SSR P8 Vented Emissions
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|

Table 5.4: Quantification Procedures
1. Project /
Baseline SSR
2. Parameter /
Variable
Emissions
Generation
Electricity
P7 Electricity
Generation (On-
Site)
Off-Grid Emission
Factor for Project
Generator Powering
Pump i/ EF
Off-Grid i
Pump Displacement
Factor for Electric
Project Pump i / PDF
Project i
Volume of Fluid
Injected by Pump i /
Vol.
Fluid i
3. Unit
4. Measured /
Estimated
5. Method 6. Frequency
7. measurement estimation frequency
Justify or and kg of CO kg of CO m
3 kWh
2
2
Project SSRs
Emissions
Electricity Generation
= Σ (EF
Off-Grid i
× (Vol.
Fluid i
/ PDF
Project i
)) e e /
fluid/kWh m
3
N/A
Estimated
Estimated
Estimated
N/A
The emission factor should be determined using Equation A3 from the Meta-Protocol
Introduction. The baseline efficiency is determined using the method described in
Section 5.2.
Estimated based on manufacturer technical specifications for project pump
Quarterly reconciliation of volumes in storage and volumes purchased.
N/A
Quantity calculated. being
Annually
This method of calculation provides a reasonable and conservative estimate of the parameter. Note that this emission source is not applicable for solarpowered pumps.
N/A
Quarterly
Reconciliation
Available from the manufacturer and should be an average under steady state operations.
It is common practice to estimate the volume of chemicals injected by pumps via volumes delivered to site.
P8
Emissions
Vented
Captured under B8 Vented Emissions
B7 Electricity
Baseline SSRs
Emissions
Electricity Generation
= Σ (EF
Off-Grid i
× (Vol.
Fluid i
/ PDF
Baseline i
))
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Generation
Site)
(On-
B8
Emissions
Vented
Emissions
Generation
Vol.
Fluid
Electricity
Volume of Fluid
Injected by Pump i / i kg of CO m
3
2 e N/A
Measured
Monthly
N/A reconciliation of volumes in storage and volumes purchased.
N/A
Monthly reconciliation
Quantity being calculated in aggregate form as fuel and electricity use on site is likely aggregate for each of these SSRs.
It is common practice to estimate the volume of chemicals injected by pumps via volumes delivered to site.
Off-Grid Emission
Factor for Baseline
Generator Powering
Pump i/ EF
Off-Grid kg of CO kWh
2 e /
Estimated
The emission factor should be determined using Equation A3 from the Meta-Protocol
Introduction. The baseline efficiency is determined using the method described in
Section 5.2.
Annually
This method and conservative estimate of the parameter. of calculation provides a reasonable
Pump Displacement
Factor for Electric
Baseline Pump i/ PDF
Baseline i
Emissions
Emissions m
3
fluid/ kWh Estimated
Estimated based on manufacturer technical specifications for project pump
N/A
Available from the manufacturer and should be an average under steady state operations.
Emissions
Vented Emissions
= Σ (Vol.
Fluid i
× PDF
Baseline i
× %Vented × ρ
CH4
× %
CH4 Fuel
/%
CH4 Reference
× GWP
CH4
);
Σ (Vol.
Fluid i
× PDF
Baseline i
× %Vented × ρ
CO2
× %
CO2 Fuel
)
Quantity
Vented kg of CO
2 e N/A N/A N/A being calculated in aggregate form as fuel and electricity use on site is likely aggregate for each of these SSRs.
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Volume of Fluid
Injected by Pump i /
Vol.
Fluid i m
3
Pump Displacement
Factor for Gas-
Powered Baseline
Pump i /PDF
Baseline i m
3
natural gas
/m
3
fluid
Percentage of gas vented from pump/
%Vented
%
Density of Methane
/ ρ CH
4
Density of Carbon
Dioxide/ ρ CO
Reference Percent
Methane in Fuel Gas
/%
CH4 Reference
2 kg / m kg / m
%
3
3
Measured
Estimated
Estimated
Constant
Constant
Estimated
Monthly reconciliation of volumes in storage and volumes purchased.
Estimated based on manufacturer technical specifications for baseline pumps. Refer to
APPENDIX A for details.
Through monitoring or statistically relevant estimation. For highbleed pumps, this parameter may be assumed to be 100%.
0.678 kg/m
3
at 15°C and
101.3kPa, the standard reference conditions used by the natural gas industry.
1.86 kg/m
3
at 15°C and
101.3kPa, the standard reference conditions used by the natural gas industry.
From manufacturer assumptions in determining technical specifications for given pump
3
Monthly reconciliation
N/A
It is common practice to estimate the volume of chemicals injected by pumps via volumes delivered to site.
Volumes of gas used to power gas-powered pumps can be estimated using information from facility operations.
N/A
Reference
Value
Reference
Value
Monitoring provides a high level of accuracy.
Statistically relevant estimates give a high level of assurance.
All values must be adjusted to standard reference conditions used by the natural gas industry.
All values must be adjusted to standard reference conditions used by the natural gas industry
N/A
Reference values from manufacturer.
3
For conservativeness, this value may be assumed as 100%.
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|

Percent Methane in
Fuel Gas /%
CH4 Fuel
Percent Carbon
Dioxide in Fuel Gas/
%CO
2
%
%
Global Warming
Potential of
Methane/ GWP
CH4 kg CO
2 e/ Kg
CH
4
Measured
Measured
Estimated
Direct Measurement
Direct Measurement
From Environment
Canada; IPCC
Annual
Annual
Annual
Fuel gas composition should remain relatively stable during steadystate operation.
Fuel gas composition should remain relatively stable during steadystate operation.
The applicable global warming potential of CH
4 is 21 as per the IPCC, ISO,
Environment Canada and other internationally accepted best practice guidance.
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5.5.2.
Accuracy
The manufacturer’s PDF is determined in a laboratory setting, under perfect conditions.
Field PDFs are typically higher due to wear and tear on the pump which causes leaks and inefficient operation. This is especially true as the pump ages. Therefore, the manufacturer PDFs used in this project underestimate the amount of gas vented to the atmosphere in both the baseline and project condition.
It is expected that there is a greater discrepancy between manufacturer’s specified PDF and actual PDF in the baseline condition, due to the older age of the baseline pumps.
Consequently, the error in manufacturer’s specifications for baseline pumps is larger than for project pumps. As a result, the amount of gas vented from the pumps is more likely to be underestimated in the baseline condition. Therefore, using manufacturer’s
PDFs gives a conservative estimate of emissions reductions.
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The project proponent should justify the selection of the Pump Displacement Factor
(PDF) based on sound engineering principles, knowledge of the pump operating characteristics, and reasonable assumptions. Examples are provided in the following section. These are used for illustrative purposes and have general assumptions. If the project proponent has access to more detailed assumptions or characteristics of the pumps, these should take precedence.
PDF for Gas Powered Chemical Injection Pumps
This section serves as a guide to establish a PDF for gas-powered pumps which can include chemical pumps, glycol pumps for dehydration unit or other pumps. The PDF for a gas-driven pump should be determined using the manufacturer technical specifications for the baseline pump. As an example, a gas powered chemical injection pump is used to pump methanol into a pipeline. The manufacturer technical specifications for gas consumption are given in Table A1.
Table A1: Gas Consumption for a Given Gas Powered Pump
4
The facility operator assumes that the pump operated with the following characteristics:
•
Piston Size-3/8”;
•
Injection Pressure- 3000 PSI; and
•
Stroke- Full
Based on these characteristics, the PDF is 243 ft
3
of gas/ gallon of chemical. In SI units the PDF is 1834.66 m
3
gas/ m
3
chemical injected.
4 http://www.arrowengine.com/media/chempump_overview.pdf
, p.9
B-I

PDF for Gas Powered Glycol Dehydrators
The determination of the PDF for glycol dehydrators follows the EPA’s methodology presented in Lessons Learned-Replacing Gas-Assisted Glycol Pumps with Electric Pumps.
The Emission Factor (EF) is defined as:
EF= PGU × G × WR × OC
Equation 6.1
Where: EF = Emissions Factor (scf natural gas /MMcf gas processed);
PGU = Pump Gas Usage (scf natural gas emitted/gallon TEG);
G = Glycol-to-Water Ratio (gallons of TEG/lb water removed);
WR = Water Removed Rate (lb water removed/MMcf gas processed); and
OC = Over circulation ratio.
The following industry accepted rules of thumb apply. Pump gas usage is 3 cubic-ft/gal for gas-assisted pumps and 1 cubic-ft/gal for electric pumps. The electric pump uses electricity only, but the vented portion of the vapours will contain fuel gas even if electric or gas-assisted pumps are used. The glycol-to-water ratio is 3 gallons TEG per pound of water.
The following numerical example shows a sample calculation.
Given: PGU = 2 scf natural gas emitted/gallon TEG;
G = 3 gallons of TEG/lb water removed;
OC = 1:1 to 2.1:1;
Inlet pressure 800 psig; and
Inlet temperature 94 ° F.
WR = 53 lb water removed/MMcf gas processed.
Using the table provided in Figure A1 , the point of intersection of the x axis
(temperature) with the 800 psig curve is read with the corresponding value on the y axis. A value of 60 lb water removed/MMcf gas processed is used as a base for WR.
Seven lb water removed/MMcf gas processed is the standard water content for pipeline gas and is subtracted from 60 lb water removed/MMcf gas processed. The amount of water that must be removed is therefore 53 lb water removed/MMcf gas processed.
PDF
5
= PGU × G × WR × OC= 2 × 3 × 53 × (Range 1.1 to 2.1)
Based on these characteristics, the PDF will range from 318 to 668 scf of natural gas emitted/MMcf gas processed. In SI units the PDF is 318 to 668 m
3
gas/ MM m
3
gas
5
The EF has been renamed PDF to keep consistency with other types of pumps and the approach being taken in the Methodology. The examples still follows the steps from the original EPA document, with the exception of the change in parameter name.
B-II

processed. The mass PDF is 228 to 478.95
kg of gas / MMm
3 gas processed assuming a density of 0.717 kg/m
3
for methane and 100% methane composition in fuel gas.
Figure A1: Water Vapour Content of Natural Gas at Saturation
6
PDF for Electrical Pumps Using Field Data
In cases where PDF cannot be established from either the manufacturer technical specifications or from pumps with similar characteristics, the parameter is estimated using field data. Essentially, the estimation of this parameter requires two data sources collected from field measurements: metering of volume of fluid displaced by type i pump and metering of electricity consumed by type i pump.
Data streams for the two metered quantities are synchronous. A deviation from this is permissible as long as the data quantities are taken over the same period and reflect steady state. Dividing the metered volume of fluid by the metered electricity consumption will establish the pump capacity. Units should be expressed as m
3 fluid/kWh.
6 http://www.epa.gov/gasstar/documents/ll_glycol_pumps3.pdf
, p16
B-III

PDF from published data
Emissions are also published in accredited sources and are used for reporting emissions to pertinent authorities. Typically, the oil and gas industry uses CAPP emission factors
(EFs). Of particular importance is the use of EFs to estimate emissions from chemical injection pumps and glycol dehydrators. It is strongly recommended that the presented in Table A2 are only used if appropriate EFs cannot be found.
Table A2: Emission Factors from CAPP
Pump Type
Gas Operated Chemical Injection Pump
Chemical Injection Pump (diaphragm)
Chemical Injection Pump (piston)
Emissions
7 , 8
0.3945 m
3
/hour/pump
0.4 m
3
/hr @ 140 kpag
0.6 m
3
/hr @ 240 kpag
0.04 m
3
/hr @ 140 kpag
0.06 m
3
/hr @ 140 kpag
Glycol Dehydration Gas pump w/o a flash separator
Glycol Dehydration Gas pump w/ a flash separator
0.2264 t CH
4
/10
6
m
3
processed gas
0.0054 t CH
4
/10
6
m
3 processed gas
Glycol Dehydration Electric pump w/o a flash separator 0.0588 t CH
4
/10
6
m
3
processed gas
Glycol Dehydration Electric pump w/ a flash separator 0.0045 t CH
4
/10
6
m
3
processed gas
7
CAPP (May, 2002). Guide- Estimation of Flaring and Venting Volumes from Upstream Oil and Gas
Facilities.
8
CAPP (June, 2003). Guide- Calculating Greenhouse Gas Emissions.
B-IV

Contingent means for calculating or estimating the required data for the equations outlined in section 4.5 are summarized in Table
B1, below.
Table B1: Contingent Data Collection Procedures
1. Project / Baseline
SSR
2. Parameter / Variable 3. Unit
Pump Displacement
Factor for Low/Nonemitting Pump/ PDF
New
Pump i m
3 fluid/kWh
P7 Electricity
Generation (On-Site)
Volume of Fluid
Displaced by Pump i /
Vol.
Fluid i m
3
fluid
Pump Displacement
Factor for High/Low
GHG Intensive Pump i
/PDF
New Pump i
B7 Electricity
Generation (On-Site)
Volume of Fluid
Displaced by Pump i /
Vol.
Fluid i m
3
fluid / kWh m
3
fluid
4. Measured
/ Estimated
5. Method
Project SSRs
Estimated based on
Estimated technical specifications for project pump of similar type
Estimated
1) Reconciliation of volume of fluid displaced within given time period
2) Estimated based on technical specifications for project pump
Baseline SSRs
6. Frequency
N/A
Monthly
Estimated
Estimated based on technical specifications for project pump of similar type
N/A
Estimated
1) Reconciliation of volume of fluid displaced within given time period
2) Estimated based on technical specifications project pump for
Monthly
7. Justify measurement or estimation and frequency
Available from manufacturer when the more accurate and precise method cannot be used.
Provides reasonable estimate of the parameter when the more accurate and precise method cannot be used.
Available from any manufacturer when the more accurate and precise method cannot be used.
Provides reasonable estimate of the parameter when the more accurate and precise method cannot be used.
C-I

Pump Displacement
Factor for High/Low
GHG Intensive Pump i
/PDF
New Pump i
Percent Methane in Fuel
Gas Used by
Manufacturer/%
CH4
Reference
B8 Vented Emissions
Fuel Gas
Percent Methane in Fuel
Gas/%
CH4 Fuel
Percent Carbon Dioxide in Fuel Gas/ %
CO2 Fuel
Volume of Fluid
Displaced by Pump i /
Vol.
Fluid i m
3
fuel gas/ m
3
fluid
Estimated
Estimated based on technical specifications for project pump of similar type
%
%
% m
3
N/A
Estimated
Estimated
Estimated
Estimated
From accredited sources or industry standards for similar types of equipment
Interpolation of previous and following measurements taken, or from fuel analysis of gas composition within the same basin.
Interpolation of previous and following measurements taken, or from fuel analysis of gas composition within the same basin.
1) Reconciliation of volume of fluid displaced within given time period
2) Estimated based on technical specifications for project pump
-
Annual
Annual
Monthly
Available from any manufacturer when the more accurate and precise method cannot be used.
Provides reasonable and conservative estimate of the parameter when the more accurate and precise method cannot be used.
Provides reasonable estimate of the parameter, when the more accurate and precise method cannot be used.
Provides reasonable estimate of the parameter, when the more accurate and precise method cannot be used.
Provides reasonable estimate of the parameter when the more accurate and precise method cannot be used.
C-II