a unified voice for canada's upstream oil and gas industry - a … · 2019-11-26 ·...

TECHNICAL REPORT

A National Inventory of Greenhouse Gas (GHG), Criteria Air Contaminant (CAC) and Hydrogen Sulphide (H2S) Emissions by the Upstream Oil and Gas Industry

Volume 1, Overview of the GHG Emissions Inventory

September 2004

2005-0011

2100, 350 – 7th Ave. S.W. Calgary, Alberta

Canada T2P 3N9 Tel (403) 267-1100 Fax (403) 261-4622

905, 235 Water Street St. John’s, Newfoundland

Canada A1C 1B6 Tel (709) 724-4200 Fax (709) 724-4225

Email: [email protected] Website: www.capp.ca

The Canadian Association of Petroleum Producers (CAPP) represents 150 companies that explore for, develop and produce natural gas, natural gas liquids, crude oil, oil sands, and elemental sulphur throughout Canada. CAPP member companies produce more than 98 per cent of Canada’s natural gas and crude oil. CAPP also has 125 associate members that provide a wide range of services that support the upstream crude oil and natural gas industry. Together, these members and associate members are an important part of a $75-billion-a-year national industry that affects the livelihoods of more than half a million Canadians.

Review by July 2010

Disclaimer

This publication was prepared for the Canadian Association of Petroleum Producers (CAPP) by Clearstone Engineering. While it is believed that the information contained herein is reliable under the conditions and subject to the limitations set out, CAPP and Clearstone Engineering do not guarantee its accuracy. The use of this report or any information contained will be at the user’s sole risk, regardless of any fault or negligence of Clearstone Engineering, CAPP or its co-funders.

Volume 1 - OVERVIEW OF THE GHG

EMISSIONS INVENTORY

A National Inventory of Greenhouse Gas (GHG), Criteria Air Contaminant (CAC) and Hydrogen Sulphide (H2S) Emissions by

the Upstream Oil and Gas Industry PREPARED BY: Clearstone Engineering Ltd. 700, 900-6 Avenue S.W. Calgary, Alberta T2P 3K2 PREPARED FOR: CAPP 2100, 350-7 Avenue S.W. Calgary, Alberta T2P 3N9 Attention: Rick Hyndman

September 2004

i

EXECUTIVE SUMMARY – GREENHOUSE GASES Purpose and Background The greenhouse gas (GHG)1 portions of this report (Volumes 1, 3 and applicable parts of 5) are intended to present a detailed inventory of GHG emissions from the upstream oil and gas sector in Canada along with explanations of the methodologies and data sources used. The type and quality of emission data available for the oil and gas sector, upon which this report is based, have significantly improved over the past several years. Furthermore, UNFCCC reporting requirements have been expanded and the type and quality of data available in Canada has changed since the previous inventory was developed. The updated inventory is required to reflect best available data and to provide a basis for Canada to meet the enhanced UNFCCC reporting requirements. The current report is based on a significant expansion of the previous work done on upstream oil and gas (UOG) methane (CH4) and volatile organic compound (VOC) emissions for the period of 1990 through 1995 and published by the Canadian Association of Petroleum Producers (CAPP) in 1999. The key improvements and changes from this previous work include the following:

• Application of a rigorous bottom-up (IPCC Tier 3) approach in which emissions have been identified at the individual facility level by primary source (e.g. fuel combustion, flaring, venting fugitive equipment leaks and accidental releases).

• Inclusion of CAC and H2S emissions. • Full compliance with UNFCCC reporting requirements and IPCC methodology and good

practice guidance for GHG emission quantification. • Quantitative assessment of the uncertainties in all presented emission estimates using an

IPCC Tier 1 methodology. • An analysis of GHG emission intensities. • To be consistent with current federal and provincial definitions, a change in the definition

of VOCs from “comprising all non-methane hydrocarbons” to “comprising all non-methane and non-ethane hydrocarbons”.

Scope Activities:

This report covers portions of the UOG industry in Canada plus the natural gas transmission and natural gas distribution industries as follows:

o well drilling, testing and servicing o light and medium oil production o cold heavy oil production o thermal heavy oil production o natural gas production

1 The target greenhouse gases are CO2, CH4, N2O, CO2E,and CO2O (atmospheric oxidation).

ii

o natural gas processing o natural gas transmission o natural gas distribution o petroleum liquids transportation o accidents and equipment failures

The UOG industry in Canada includes petroleum exploration activities; well drilling, testing and servicing; conventional oil and gas production; frontier/offshore oil and gas production; in-situ bitumen production; bitumen mining and extraction; heavy oil and bitumen upgrading; natural gas processing; and petroleum liquids transmission. Specific segments of the industry excluded from the inventory are petroleum refining, heavy oil upgrading and oilsands mining, extraction and upgrading. Natural gas transmission, storage and distribution were not part of the inventory compiled for this project. However, emission totals by province are included based on work conducted by ICF Consulting Canada Inc. for the Canadian Natural Gas Partnership for Energy and the Environment (ICF 2000), as supplemented by additional information from the Canadian Gas Association (CGA 2004).

While it was essential to engage all of the petroleum producing provinces and territories, the primary focus was on the three provinces that represented 95% of UOG total hydrocarbon (THC) emissions (in 1995, Alberta, Saskatchewan and British Columbia accounted for 95% of the total of 2,276 kt of THC releases, with Alberta alone accounting for 70% of total releases).

Facilities:

Emissions from all facets of the subject portions of the oil and gas sector are covered by this report except for construction operation, ancillary structures and operations (buildings, offices, etc.) and mobile sources.

Timeframe:

This report provides the results of a detailed ‘bottom-up’ inventory of emissions from the UOG sector for the year 2000. These results have been extrapolated at a sub-sector level for all subject activities for all years 1990 through 1999.

Emission Sources:

The primary types of emission sources covered in this report are: o fuel combustion, o flaring, o formation CO2 releases, o reported and unreported venting, o fugitive equipment leaks, o storage and handling losses, and o accidental releases.

iii

Methodology The aim has been to develop a practicable and defensible methodology that takes advantage of currently available information, and provides sensible methods for managing uncertainties and bridging data gaps. Preplanning of the inventory, involvement of government and industry experts throughout the emissions inventory development, and documentation of the applied methodology have provided a practical mechanism for ensuring transparency to stakeholders and interest groups, while promoting a constructive review process to help ensure a high-quality cost-effective product. The primary objectives considered in developing this methodology were as follows:

• spatial allocation of emissions (i.e., latitude, longitude and area), • disaggregation of emissions by type and size of facility, • inclusion of area, point and transient sources, • synergy with national reporting of GHG emissions, • efficient future updating of the inventory (i.e., use of surrogate data), • compliance with good practice in managing uncertainties in emissions inventory, and • general compliance with current UNFCCC reporting formats.

For the year 2000, the emissions inventory was developed using an IPCC Tier 3 bottom-up assessment methodology beginning at the individual facility and process unit level. Compliance with IPCC good practice guidance was maintained throughout. Both emissions due to fuel use and fugitive sources have been evaluated, and the results are summarized in a manner consistent with the UNFCCC common reporting format. This type of approach evaluates the emissions on a source-by-source basis and aggregates the results to ultimately provide emission estimates by facility and geographic area. Typically, facilities are identified as point sources and their coordinates are given in degrees longitude and latitude. All compiled data were converted to a consistent format for processing using a single database application. The assumptions and techniques used to bridge data gaps are highlighted. The overall aim was to provide the best emission estimates possible based on the information available. Further, quantitative estimates of the uncertainties in all presented emission estimates were determined using an IPCC Tier 1 approach. A qualitative discussion of the uncertainties and specific assumptions used in the inventory, as well as a detailed description of the applied methodologies are provided in Volume 3. A compendium of all applied emission factors and uncertainty data is provided in Volume 5. Time series consistency has been maintained for the 1990 to 2000 results. Where historical data are missing, back-casting techniques were used to establish an acceptable relationship between emissions and activity data in accordance with IPCC Good Practice Guidance (Chapter 7 Methodological Choice and Recalculation, Section 7.3.2). The development of the inventory has included substantial government and industry involvement and review to ensure the most accurate and complete results possible. The methodology employed was developed under the direction of a sub-group (SG) of the EPWG to insure that the appropriate expertise has been engaged. The developed inventory builds upon the preceding

iv

work of the UOG Industry SG established under the NPRI Multi-stakeholder Work Group on Substances (2001 to 2002) and on the previous CH4 and VOC emission inventories published by CAPP. Information Sources The emissions inventory has drawn on the best and most detailed information available from government, industry and other published and unpublished sources. The key information sources used in the development of the inventory include:

• Production accounting data, equipment and facility lists, emission monitoring data, spill reports, drilling and well testing data, environmental impact assessments, site inspection reports and other such information available from government agencies (e.g., Alberta Energy and Utilities Board, British Columbia Oil and Gas Commission, Saskatchewan Industry and Resources and the National Energy Board):

o Relevant statistics, databases, study results, emission factors and speciation profiles, emission calculation protocols and survey information available from industry associations.

o Data available from individual UOG companies and their designated data administrators (e.g., equipment and activity data maintained by external information systems service providers, etc).

o Canadian and international sources of emission factors and speciation profiles (primarily government agencies, industry associations and the open literature).

o Emissions data compiled by Clearstone Engineering Ltd. (Clearstone) from numerous measurement programs and emissions studies conducted at different facilities throughout the UOG industry where prior permission for use of this data has been obtained from the original clients.

• The glycol dehydrator database from CAPP. • Drilling activity and fuel use data from The Canadian Association of Oilwell Drilling

Contractors. • Relevant emission factors available from Environment Canada, U.S. Environmental

Protection Agency, Clearstone’s in-house databases, and other such information. • An industry survey conducted through CAPP to obtain facility-level equipment lists,

fuel purchases from third parties, compression ratios, API gravity, steam volume and quality, produced water salinity, electric power production, and steam purchases.

Results Total GHG emissions by source type, sub-sector, facility type and sub-type, for the year 2000 at the national level are presented below in Table A. A more detailed version of Table A is presented in Section 9.0 (Appendix A). Total carbon dioxide equivalent (CO2E) GHG emissions from the oil and gas sector (including gas transmission, storage and distribution) in 2000 were 101 211 kilotonnes (kt). For the subject UOG

v

sub-sectors, total GHG emissions were 84 355 kt with an uncertainty of ±1.5 percent. This amounts to 12 percent of Canada’s total (net) national emissions of GHGs in 2000 and is an increase of approximately 25 percent from the 1995 inventory (CAPP 1999). The contribution by type of GHG gas to total emissions is 44 866 kt CO2 (53.2 percent of CO2E), 1 849 kt CH4 (46.0 percent of CO2E) and 2.13 kt from N2O (0.8 percent of CO2E). The atmospheric oxidation of all non-CO2 carbon-containing gases (e.g., as CO or THC) contributes a further 7 234 kt of CO2 equivalent. By sub-sector (type of activity), gas processing accounts for 25.1 percent, gas production 24.0 percent, heavy oil and cold bitumen production 22.1 percent, light and medium crude oil production 11.9 percent, and thermal heavy oil and bitumen production 8.5 percent. These contributions are roughly in proportion to the amount of combustion activities that occur in these various sub-sectors of the industry and the relative size of the sub-sector. Combined natural gas production and processing contribute almost one-half of GHG emissions from the UOG sector. The greatest primary source of the estimated CO2E emissions is fuel combustion which accounts for 40.8 percent of the total, followed by reported venting (15.7 percent), fugitive equipment leaks (11.9 percent), unreported venting (11.4 percent), releases of formation CO2 (8.1 percent), flaring (6.2 percent), accidental releases (5.0 percent), storage losses (1.0 percent), and loading/unloading losses (less than 0.1 percent). Nearly three quarters of the CO2 emissions are from fuel combustion, with most of the rest coming almost equally from flaring and releases of formation CO2. N2O emissions are almost entirely from fuel combustion and CH4 emissions are predominantly from the various types of venting and fugitive equipment leaks. These UOG results are summarized in a tabular format at the national and provincial level for the years 1990 through 2000 (Section 11). Graphical representations of GHG emissions by type of greenhouse gas and by province are presented in Section 12. Additionally, emission intensity data are presented by type of facility for the year 2000 where data allow (Section 13). A provincial breakdown of GHG emissions for the natural gas transmission, storage and distribution sub-sectors in Canada are also presented for the year 2000 (Section 10) based on ICF 2000 work. A detailed facility level database of GHG emissions is provided along with the report.

vi

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (kt CO2E)

Emission Source Type

Activity Type Facility Type Facility Sub-Type (or activity sub-type)

Fuel Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported

Fugitives: Equipment And Other

Total

(drilling) 1 285 1 285 Well (drill-stem testing) 10 7 16

Well Drilling

Sub Total All 1 285 10 7 1 301 (service rigs) 144 144 (pumping units) 177 177

Well

(blowdown treatments) 220 220

Well Servicing

Sub Total All 321 220 541 Well (well testing) 890 92 981 Well Tests Sub Total All 890 92 981

L/M Crude Oil – Flowing 1 2 1 4 Well L/M Crude Oil – Pumping 4 5 12 20 Crude Oil – Single 291 681 439 1 226 1 024 3 661 Crude Oil – Satellite 1 347 630 351 553 618 3 499

Battery

Crude Oil – Group 974 1 010 59 453 324 2 819 Disposal Water 1 1

Light/Medium Crude Oil Production

Sub Total All 2 617 2 320 850 2 238 1 979 10 004 Heavy Crude Oil – Primary/Secondary 2 022 848 2 870

Well

Oil Sands - Cold 301 94 394 Crude Bitumen – Single 179 121 2 689 395 386 3 770 Crude Bitumen – Satellite 632 331 681 352 235 2 230 Crude Bitumen – Group 544 100 4 945 188 121 5 899 Oil Sands – Single 86 82 1 919 56 32 2 176 Oil Sands – Satellite 31 26 740 12 32 840

Battery

Oil Sands – Group 31 43 355 4 52 486

Heavy Crude Oil From Cold Production

Sub Total All 1 504 703 11 329 3 330 1 799 18 665 Heavy Crude Oil - Thermal negl. negl. Well Oil Sands - Thermal negl. negl. Crude Bitumen - Group 402 18 374 27 5 826 Battery Oil Sands - Group 5 639 267 415 2 6 6 329

Disposal Water negl. negl.

Heavy Crude Oil From Thermal Production

Sub Total All 6 042 285 789 29 11 7 156 Natural Gas – Shallow – All 3 31 160 194 Natural Gas – Deep – Sweet 39 144 139 322

Well

Natural Gas – Deep – Sour 23 6 8 36 Gathering System 6 168 132 896 1 467 8 662

Natural Gas Production

Gathering System Compressor Station 1 057 21 4 271 347 1 700

vii



Activity Type Facility Type Facility Sub-Type (or activity sub-type)

Fuel Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported

Fugitives: Equipment And Other

Total

Meter Station 35 94 129 Meter/Regulation Station 2 17 19 Regulator Station 3 36 39 Natural Gas – Single 168 25 8 1 020 1 076 2 297 Battery Natural Gas – Group 2 233 78 144 2 269 2 152 6 876

Disposal Gas Injection 1 1 Sub Total 9 690 255 157 4 677 5 497 20 276 Sweet Natural Gas Plant All 3 320 116 8 68 575 4 088 Sour Natural Gas Plant – Acid Gas Flaring

All 1 944 128 649 35 76 2 832

Sour Natural Gas Plant – Acid Gas Injection

All 954 61 10 21 1 046

Sour Natural Gas Plant – Sulphur Recovery

All 5 696 207 6 155 23 55 12 137

Straddle Natural Gas Plant All 1 058 12 4 23 1 097

Natural Gas Processing

Sub Total All 12 973 524 6 805 139 750 21 199 Natural GasTransmission All 12 286 1 308 1 969 15 563 Natural Gas Distribution All 81 96 988 1 165 Storage as Natural Gas All 36 13 65 113 Storage as LNG All 6 3 7 15

Natural Gas Transmission / Distribution

Sub Total All 12 409 1 420 3 028 16 857 All All 9 negl. negl. 9 Pump Station All 2 negl. 2

Pipeline Terminal 19 negl. 19 Production Tank 4 negl. 4

Storage

Tank Farm 1 negl. 1

Petroleum Liquids Transportation

Sub Total All 9 26 negl. 35 All (natural gas migration) 42 42 All (pipeline ruptures) 834 834 All (spills) 5 5 All (surface casing vent flows) 3 217 3 217

Accidents and Equipment Failures (unallocated)

Sub Total All 4 197 4 197 Total All All 46 840 5 216 6 805 14 636 10 445 17 262 101 211

ix

TABLE OF CONTENTS

1.0 INTRODUCTION 1 2.0 BACKGROUND 2 3.0 SCOPE 3

3.1 Activities 3 3.2 Facilities and Equipment 3

3.2.1 Natural Gas System 3 3.2.1.1 Gas Production and Processing 4 3.2.1.2 Gas Transmission and Storage 10

3.2.2 Crude Oil System 10 3.2.2.1 Oil Production and Treatment 10

3.2.3 Oil Transport 13 3.3 Timeframe 14 3.4 Target Greenhouse Gases 14 3.5 Emission Sources 15

4.0 OVERVIEW OF RESULTS 17 4.1 CO2 Equivalent Emissions 17 4.2 CO2 Emissions 18 4.3 CH4 Emissions 18 4.4 N2O Emissions 18 4.5 CO2 Atmospheric Oxidation Emissions 18

5.0 COMPARISONS WITH OTHER INVENTORIES 25 5.1 Comparison with the CAPP 1995 Inventory 25

6.0 EMISSION INTENSITY ANALYSIS 28 7.0 CONCLUSIONS AND RECOMMENDATIONS 31

7.1 Conclusions 31 8.0 REFERENCES CITED 32 9.0 APPENDIX A: TABULAR SUMMARY OF EMISSIONS FOR YEAR 2000 33 10.0 APPENDIX B: SUMMARY OF GHG EMISSIONS FROM GAS TRANSMISSION,

STORAGE AND DISTRIBUTION 42 11.0 APPENDIX C: HISTORICAL SUMMARY OF EMISSIONS BY PROVINCE/

TERRITORY 49 12.0 APPENDIX D: GRAPHICAL SUMMARY OF THE INVENTORY BY PROVINCE 195 13.0 APPENDIX E: GHG EMISSION INTENSITY PLOTS BY TYPE OF FACILITY 198

x

LIST OF ACRONYMS AGA - American Gas Association BSFC - brake-specific fuel consumption CAC - criteria air contaminant CAPP - Canadian Association of Petroleum Producers CCME - Canadian Council of Ministers of the Environment CGA - Canadian Gas Association CH4 - methane CO2O - carbon dioxide form atmospheric oxidation CO2E - carbon dioxide equivalent CSA - Canadian Standards Association EC - Environment Canada GHG - greenhouse gases GRI - Gas Research Institute GTC - Gas Technology Canada H2S - hydrogen sulphide HEL - higher explosive limit HHV - high (or gross) heating value IPCC - International Panel on Climate Change kt - kilotonnes LEL - lower explosive limit LHV - lower (or net) heating value N2O - nitrous oxide NBS - National Bureau of Standards NMHC - non-methane hydrocarbon NPRI - National Pollutant Release Inventory PM - total suspended particulate matter PM2.5 - particulate matter ≤ 2.5 µm in aerodynamic diameter PM10 - particulate matter ≤ 10 µm in aerodynamic diameter POM - polycyclic organic matter ppm - parts per million SEPAC - Small Explorers and Producers Association of Canada THC - total hydrocarbons TOC - total organic compounds TNMOC - total non-methane organic compounds UOG - upstream oil and gas UNFCCC - United Nations Framework Convention on Climate Change U.S. EPA - U.S. Environmental Protection Agency VCR - Voluntary Challenge and Registry VOC - volatile organic compound

xi

CONVERSIONS

USEFUL CONVERSION FACTORS

Physical Quantity

SI to English Conversion

English to SI Conversion

Length

1 m =3.2808 ft 1 km = 0.6213712 mi

1 ft = 0.3048 m 1 mi = 1.609344 km

Area

1 m2 = 10.7639 ft2

1 ft2 = 0.092903 m2

Volume

1 m3 = 35.3134 ft3 1 L = 0.2641720 U.S. gal

1 ft3 = 0.02837 m3 1 U.S. gal = 3.785412 L

Velocity

1 m/s = 3.2808 ft/s 1 km/h = 0.6213712 mph

1 ft/s = 0.3048 m/s 1 mph = 1.609344 km/h

Density

1 kg/m3 = 0.06243 lbm/ft3

1 lbm/ft3 = 16.018 kg/m3

Force

1 N = 0.2248 lbf

1 lbf = 4.4482 N

Mass

1 kg = 2.20462 lbm

1 lbm = 0.45359737 kg

Pressure

1 kPa = 0.145038 psi 1 kPa = 4.01474” WC

1 psi = 6.89476 kPa 1” WC = 0.249082 kPa

Energy

1 kJ = 0.94783 Btu

1 Btu = 1.05504 kJ

Power

1 W = 3.4121 Btu/h 1 kW = 1.3405 hp

1 Btu/h = 0.29307 W 1 hp = 0.746 kW

Heat Flux/Unit Area

1 W/m2 = 0.317 Btu/h·ft2

1 Btu/h·ft2 = 3.154 W/m2

Heat Flux/Unit Length

1 W/m = 1.0403 Btu/h·ft

1 Btu/h·ft = 0.9613 W/m

Heat Generation/Unit Volume

1 W/m3 = 0.096623 Btu/h·ft3

1 Btu/h·ft3 = 10.35 W/m3

Energy/Unit Mass

1 kJ/kg = 0.4299 Btu/lbm

1 Btu/lbm = 2.326 kJ/kg

Specific Heat

1 kJ/kgºC = 0.23884 Btu/lbmºF

1 Btu/lbm·ºF = 4.1869 kJ/kg·ºC

Thermal Conductivity

1 W/mºC = 0.5778 Btu/h·ftºF

1 Btu/h·ft·ºF = 1.7307 W/m·ºC

Convective Heat Transfer Coefficient

1 W/m2C = 0.1761 Btu/h·ft2·ººF

1 Btu/h·ft2·ºF = 5.6782 W/m2·ºC

xii

ACKNOWLEDGEMENTS The development of this document has been sponsored by CAPP, Environment Canada, Natural Resources Canada, Canadian Energy Pipeline Association, Canadian Gas Association, Alberta Energy and Utilities Board, Alberta Environment, BC Ministry of Water, Land and Air Protection, and Saskatchewan Industry and Resources. The assistance and contributions provided by the many agencies and companies contacted as part of this study are gratefully acknowledged. As well, special thanks are given to the project steering committee for the support, direction, and constructive reviews they have provided:

• Roy McArthur (Environment Canada – Pollution Data Branch) • Rick Hyndman (Canadian Association of Petroleum Producers) • Matin Afshin (Environment Canada – Pollution Data Branch) • Tracy Bell (Imperial Oil) • James Brown (Shell Canada Limited) • Geoff Browning (Natural Resources Canada) • Sheila Chernys (Petro-Canada Resources) • Richard Clark (Murphy Oil Company Ltd.) • Bob Collins (Yukon Energy Mines and Resources) • Marc Deslauriers (Environment Canada – Pollution Data Branch) • Kendall Dilling (Encana Corporation) • John Drinkwater (BP Canada Energy Company) • Cristina Dumitras (Environment Canada – Pollution Data Branch) • Paula Dunlop (Canadian Gas Association) • Sam Edgerton (Nexen Canada Ltd.) • Dave Fox (Environment Canada – Yellowknife) • Chia Ha (Environment Canada – Pollution Data Branch) • Andrew Higgins (Talisman Energy Inc.) • David Hill (Alberta Energy Utilities Board) • Wayne Hillier (Husky Energy) • Tony Irwin (Canadian Energy Pipeline Association) • Roy Kanten (Shell Canada Limited) • Orest Kotelko (Canadian Natural Resources Limited) • Howard Loseth (Saskatchewan Industry and Resources) • Lon Nadler (Natural Resources Canada) • Frank Neitzer (Natural Resources Canada) • David Niemi (Environment Canada – Pollution Data Branch) • Kenneth Olsen (Environment Canada – Pollution Data Branch) • Michelle Reinsborough (Natural Resources Canada) • Stephen Rodrigues (Canadian Association of Petroleum Producers) • Darwin Roske (Saskatchewan Industry and Resources) • John Squarek (Canadian Association of Petroleum Producers) • Sari Shilson (BC Ministry of Energy and Mines) • David Slubik (Alberta Environment) • Dan Woo (Environment Canada – Edmonton)

1

1.0 INTRODUCTION This volume presents an overview of the greenhouse gas (GHG) emissions inventory for the subject portions of the oil and gas sector in Canada. A brief description of the scope of the analysis undertaken and parameters covered are given in Section 3. Section 4 provides an overview of the results of the analysis by activity and emissions source for each subject GHG. A comparison with other inventories is presented in Section 5. Section 6 presents the initial results of the GHG emissions intensity analysis conducted in conjunction with the inventory work. The conclusions from this work and specific recommendations for future studies are given in Section 7. All references cited in this volume are listed in Section 8. Detailed tabular summaries of the emissions inventory are provided in the Appendices (Sections 9 to 12). Section 13 contains graphical summaries of the intensity analysis work. The methodologies, assumptions, calculation procedures, information sources and emission factors used to develop the GHG emission inventory for the UOG sector are described in the following volumes:

• Volume 3: GHG Methodology • Volume 5: Compendium of Terminology, Information Sources, Emission

Factors and Uncertainty Data

2

2.0 BACKGROUND A brief description of the upstream oil and gas (UOG) sector is provided below. Most Canadian crude oil and natural gas production is from the Western Canadian sedimentary basin in Alberta, Saskatchewan and British Columbia. In 2000, these three provinces accounted for over 89 percent of Canada’s total oil production and 96 percent of its natural gas production (see Table 1). The provinces of Manitoba, Ontario, Nova Scotia and Newfoundland, as well as the Yukon and Northwest Territories account for the rest. Table 1. Summary of Natural Gas and Crude Oil Production by

Province/Territory for Year 2000.

Province/Territory


(106 m3)

Light/Medium Oil Production

(103 m3)

Heavy Oil Production

(103 m3)

In-Situ Bitumen

Production (103 m3)

Northwest Territories1 754.2 1 434.2 ---- ----Yukon Territory1 569.6 ---- ---- ----British Columbia2 25 516.6 2 563.4 ---- ----Alberta3 176 145.9 29 681.5 13 822.3 16 780.9Saskatchewan4 8 147.8 12 657.3 11 585.4 ----Manitoba5 13.7 625.1 ---- ----Ontario6 420.0 232.3 ---- ----Nova Scotia1 3 597.2 ---- ---- ----Newfoundland1 2 393.4 8 394.2 ---- ----Canada 217 558.4 55 588.0 25 407.7 16 780.9

1. Source: Statistics Canada. 2000. Supply and Disposition of Crude Oil and Natural Gas. Catalogue No. 26-006-XPB.

2. Source: British Columbia Oil and Gas Commission. British Columbia Annual Oil and Gas Statistics - 1966 to 2001. Available on the website: http://www.ogc.gov.bc.ca

3. Source: Alberta Energy and Utilities Board. 2000. Alberta Energy Resource Monthly Statistics. ST 3-2000.

4. Source: Saskatchewan Industry and Resources. 2000. Mineral Statistics Yearbook 2000. Miscellaneous Report 2000-3.

5. Source: Manitoba Industry, Trade and Mines. 2000 Manitoba Oil Activity Review. Available on the website: www.gov.mb.ca/itm/petroleum/oar/index.html

6. Source: Ontario Oil, Gas & Salt Resources Library. Database available at www.ogsrlibrary.com

3

3.0 SCOPE 3.1 Activities This report covers a number of areas of activity of the UOG industry in Canada plus the natural gas transmission and natural gas distribution industries as follows:

o well drilling and servicing, o light and medium crude oil production, o heavy crude oil cold production, o heavy crude oil thermal production, o natural gas production, o natural gas processing, o natural gas transmission, o natural gas distribution, and o petroleum liquids transportation.

This report also covers emissions from accidents and equipment failures which are not attributed to any particular sub-sector within the UOG sector. The following areas of activity are not covered:

• Petroleum refining and the distribution and use of refined petroleum products, as these are part of the downstream side of the industry.

• Bitumen mining and extraction and heavy oil and bitumen upgrading, as these are currently being assessed as part of a separate project being undertaken for CAPP.

GHG emissions from natural gas storage, transmission and distribution have been previously determined by others (ICF 2000 and CGA 2004) and, therefore, are simply summarized here for easy reference. 3.2 Facilities and Equipment All facilities and equipment used to conduct the above noted activities are covered in this report with the exceptions of ancillary structures and operations (buildings, offices, etc.), mobile sources and any facilities and equipment related to construction activities. 3.2.1 Natural Gas System

The natural gas system may be subdivided into four main parts:

• Gas Production, • Gas Processing, • Gas Transmission and Storage, and

4

• Gas Distribution.

Figures 1 to 3 present high-level flow diagrams showing the key infrastructure elements of each of these parts of the gas system. Gas production and processing are depicted in Figure 1 and gas transmission and distribution are presented in Figures 2 and 3, respectively. Not all of the indicated elements necessarily exist in all applications, and the size and extent of atmospheric emissions at a given type of facility will vary with site-specific circumstances (e.g., amount of production, age of facility, operating practices, quality of maintenance and inspection programs, operating conditions, and regional regulatory requirements). Only, the first two segments of the natural gas system are considered part of the upstream industry, and, therefore, are part of the UOG inventory. The primary types of atmospheric emissions sources that may occur at gas facilities are, depending on the type of facility: equipment leaks, venting by gas operated devices, process venting and flaring, fuel combustion by process equipment, evaporation losses from both flashing and stable natural gas liquids (NGL) during storage, loading, unloading and handling, and releases from accidents and equipment failures. The main sources of venting and flaring are reboiler vents on glycol dehydrators, use of natural gas as the supply medium for gas-operated devices (e.g., instrument control loops, chemical injection pumps, and compressor starters), depressurization of equipment for inspection and maintenance purposes, depressurization of pipeline segments to facilitate tie-ins (e.g., new wells, installations or pipeline segments), pigging activities, well testing and servicing activities, venting of formation CO2 extracted from the raw gas at gas processing plants, flaring of acid gas at sour (flaring) gas processing plants, and venting/flaring episodes during process upsets to relieve excess pressure, dispose of off-specification product, or help clear blockages in lines (e.g., hydrates). Fuel requirements are usually greatest at natural gas compressor stations and processing facilities. 3.2.1.1 Gas Production and Processing

The aim of natural gas production and processing activities is to produce a saleable natural gas product that meets the applicable gas transmission and distribution specifications. Typical sales specifications require that the natural gas be supplied at a specific pressure (usually, in the order of 8000 kPa) and satisfy gas quality requirements with respect to hydrocarbon dew point, water dew point, sulphur content, and heating value. The purpose is to ensure a clean, non-corrosive, non-toxic, natural gas mixture of predominantly methane that will not freeze or begin to condense at transport or final receipt conditions. Any hydrocarbon liquids that may be produced in association with the natural gas (i.e., natural gas liquids) or extracted at gas processing plants

8

are transferred into the oil system, but may be a source of vapour emissions at the gas facilities where these liquids occur. The types and intensity of atmospheric emissions from natural gas production and processing is primarily a function of the type of gas being produced, namely: dry, wet or associated gas.

Dry Natural Gas Dry gas is raw natural gas from gas wells that only needs to be compressed and dehydrated to meet sales specification (i.e., it contains very little heavier-than-methane hydrocarbons or impurities besides water vapour). This gas comes from shallow wells (i.e., less than 1000 m deep) and is usually comprised of at least 95 percent methane. Some free water may occur in association with the produced gas.

Dry gas is usually collected in low-pressure gathering systems (e.g., below 525 kPa), and conducted to a gas battery where it is dehydrated and compressed into a gas transmission system. A pressure regulator and possibly pigging facilities are provided at each well. Metering to determine the production rate from each well is either provided at the well or at the battery. Depending on the length of the gathering system, booster compressors may be provided on some sections of the gathering system. As well, field separators may be installed at various locations to remove free water from the system. Wet Natural Gas Wet gas is raw natural gas from gas wells that requires processing to remove condensable hydrocarbons (i.e., to meet hydrocarbon dew point specifications) and, in addition to dehydration, may require some sweetening to remove excessive levels of CO2 and H2S. The concentration of CO2 and H2S in the raw gas is reservoir-dependent, but tends to increase with the depth of the source reservoir.

The amount of compression required depends on the depth of the reservoirs, the stage of the exploitation cycle, gathering distances, and sales requirements. Some free hydrocarbon liquids and free water often occur in association with the produced gas.

Wet natural gas is collected at higher pressures (typically greater than at least 1000 kPa) and transported to a gas plant for processing before entering the gas transmission system. Each well will have flow control and

9

metering facilities. Compressors may be located at some wells and at various points on the gathering system. Hydrate control is an important consideration in the design of these gathering systems. Hydrates are solid crystalline ice-like structures composed of water and hydrocarbon molecules that can form in pipelines and stop the flow. Two main gathering system designs are used: heated and dehydrated systems. Usually, heated gathering systems are employed if the gas is sour, and dehydrated systems are used if the gas is sweet. Heated gathering systems guard against the formation of hydrates by maintaining the gas temperature above some critical value. This temperature control is achieved by installing line heaters at appropriate points along the gathering system. The minimum temperature to be maintained depends on the composition and pressure of the gas. Consequently, it varies from one system to the next. Dehydrated gathering systems prevent hydrates by removing water vapour from the process gas using dehydrators installed at appropriate junctions or receipt points on the gathering system. Absorption by diethylene or triethylene glycol is the most widely used dehydration process for this purpose. Desiccant dehydrators, although much less common, are also used. Emergency shutdown (ESD) valves may be installed at selected intervals along the pipeline to minimize the amount of gas released in the event of a line break, especially if the gas is sour.

The gas processing plant will feature a selection of process units to treat and purify the gas as required, and may include both inlet and sales compression. Associated Gas Associated gas (also sometimes referred to as solution gas) is raw natural gas produced from oil wells in association with the oil production. It is usually rich in condensable hydrocarbons and may contain some CO2 and H2S. Usually associated gas is used for on-site fuel requirements at the oil production facility, and any surplus is then vented or flared (i.e., if it is uneconomical to conserve), reinjected to maintain reservoir pressure or produced into a gas gathering system and ultimately processed and purified.

10

3.2.1.2 Gas Transmission and Storage

The natural gas transmission system conducts sales-quality natural gas from the producers (i.e., from gas batteries, gas processing plants and imports at the border) to market (i.e., gas distribution systems, the border for export, and direct sales to end customers). There are several straddle plants and a number of natural gas storage facilities located on the gas transmission pipeline system. The straddle plants feature a high-capacity cryogenic deep-cut liquid extraction process designed to remove any residual ethane and heavier hydrocarbons left in the gas by the upstream gas processing plants. Although located on the gas transmission system, straddle plants are evaluated under gas processing and production. The storage facilities accommodate fluctuating differences between gas supply and demand rates. These facilities usually feature an underground cavern with multiple wells for injection/removal of the gas. In addition, they include compressors to recompress stored gas when it is removed from the cavern, and dehydration facilities for removal of any moisture the gas may have picked up in the cavern. There are also some storage facilities in Canada where natural gas is liquefied and stored in spherical vessels. These types of storage facilities are normally located near the start of gas distribution systems. They feature a liquefaction plant at the inlet to the storage vessels and a vapourizer and compression at the outlet to the vessels.

3.2.2 Crude Oil System

The crude oil system comprises all facilities and associated infrastructure used to produce, treat, and transport to market, light, medium, and heavy crude oils, and crude bitumen from enhanced recovery projects (see Figure 4). In addition to produced crude oil, the transportation segment of the system may also receive and transport synthetic crude oil from oil sands operations, upgrader products and gas plant liquids. Heavy oil upgraders and oil sand facilities are specifically excluded from the scope of this study. 3.2.2.1 Oil Production and Treatment

The production and treatment segment of the crude oil system may comprise the following infrastructure:

• Wells,

11

•

12

• Flow lines or tanker services to transport the well effluent to a battery or cleaning plant.

• Single-well, satellite and central batteries.

A battery is a production unit where effluent from one or more wells is separated into its constituent phases (i.e., oil, gas and water) for metering and appropriate disposition. The oil is pumped into a nearby crude oil pipeline, or shipped by truck or tanker to a location where this may be done. The gas is used for fuel, where practicable, and the balance is vented, flared, reinjected or compressed into a nearby gas gathering system. The produced water is either reinjected as part of an enhanced recovery scheme, or is shipped to a nearby disposal well. A single-well production unit is the simplest type of oil battery. As a minimum, it is equipped with separation, metering, product storage and loading, and flaring facilities. Depending on the amount and nature of the production, it may also comprise selected treatment, pumping and compression facilities. Oil batteries that are connected to a crude oil pipeline have treater facilities for removing any water in emulsion with the oil. Other oil batteries usually only have separation and storage facilities, and the oil is transported to another larger oil facility for treating. A satellite battery is an intermediate production facility. It is located between a group of wells and a central battery. There are two separators and associated sets of metering at each satellite battery. One train is used to compile proration data on the commingled effluent from all but one of the connected wells (i.e., the group train). The other one (i.e., the test train) is used to test the remaining well. A regular test is performed on each of the wells. Typically, there are no storage or treatment facilities at satellite batteries, and no gas is vented or flared. Consequently, the oil, water and gas stream are typically recombined prior to being transported to a central processing facility for separation. A central battery is the same as a single-well battery except that it receives production from more than one well, and is usually much larger. Like the satellite battery, it will feature both a group and test separation and metering train.

The size and design of oil production facilities depends greatly on the type of crude oil production (namely conventional [light or medium density] crude oil, heavy crude oil or crude bitumen), the spacing of wells, production rates, life expectancy of the field, the distance to an oil

13

transmission pipeline, the gas-to-oil (GOR) ratio of the production, the concentration of H2S in produced oil and gas, and the type of recovery scheme.

3.2.3 Oil Transport

This category comprises tanker vehicles and transmission pipelines used to move crude oil, natural gas liquid (NGL), and liquefied petroleum gas (LPG) from producers (i.e., oil batteries, upgraders, oil sands plants, gas processing plants and border import points) to market (i.e., refineries, petrochemical plants and border export points). The key elements of oil transportation systems are the shipping and receiving terminals and pump stations. Pipelines move most oil. Surface transportation is usually only used to move oil from a source to the pipeline where this is more economical than expanding the nearest pipeline network. Surface transportation may be provided by tanker trucks, tanker rail cars or marine tankers, depending on the circumstances.

14

3.3 Timeframe This report provides a summary of the GHG emission inventory for the year 2000. GHG emissions estimates at a sub-sector and facility type level are provided for the time period 1990 through 1999. 3.4 Target Greenhouse Gases The target GHGs are CO2, CH4 and N2O. CO2 primarily occurs as a product of fuel and waste gas combustion; however, significant amounts of CO2 initially present in the produced oil and gas (i.e., formation CO2) may also occur. CH4 is contributed primarily due to venting and fugitive emissions, but also is a product of incomplete fuel or waste gas combustion. N2O is a product of combustion and a constituent of oxides of nitrogen (NOx). Relatively little data are available on N2O although it is noteworthy that techniques used to minimize NOx production, such as the creation of reducing environments or the application of post-combustion treatment technologies, especially those involving the use of catalysts, tend to actually contribute to the formation of N2O. Small emissions of other GHGs may also occur at UOG facilities (e.g., HFCs, CFCs and SF6); however, these are excluded from the scope of the present work. The total radiative forcing contributed by the sum of the target GHG emissions is expressed in terms of an equivalent emission of CO2. This is done by applying the following global warming potentials specified by UNFCCC (2002): 1 for CO2, 21 for CH4 and 310 for N2O. Additionally, IPCC (1996) practice is to account for all releases of carbon to the atmosphere as CO2 except unoxidized carbon emitted in a solid (or stored) form such as particulate matter, soot or ash. In general, carbon emitted in a solid form is assumed to remain stored indefinitely (i.e., not emitted in gaseous form). Carbon released as carbon monoxide (CO), methane (CH4), or non-methane hydrocarbons (NMHC) is evaluated separately from, and in addition to, the CO2 emission assessment. This apparent double counting allows for the fact that these non-CO2 compounds all oxidize to CO2 in the atmosphere within a period of a few days to about 12 years, depending on the substance. For combustion sources, the IPCC accounting of GHG contributions due to atmospheric oxidation of non-CO2 gases is implicitly accounted for in the applied factors. The CO2 emission factors for fuels assume complete conversion of all carbon to CO2 except that portion which is emitted in a solid form. For non-combustion sources, the IPCC requirements for including contributions due to atmospheric oxidation of the associated non-CO2 emissions are not explicitly stated in either IPCC methodology manual or good practice guidance, but are currently being emphasized through the UNFCCC Secretariat’s national inventory review process. Here contributions due to atmospheric oxidation of non-CO2 emissions by non-combustion sources are calculated and reported separately as CO2O (i.e., equivalent CO2 emissions due to atmospheric oxidation of non-CO2 emissions from non-combustion sources).

15

3.5 Emission Sources The primary GHG emission sources covered in the current UOG inventory are as follows: • Fuel Combustion – comprises the combustion of fuel withdrawn from the process and fuel

purchased from third parties. The amount of fuel withdrawn from the process was determined directly from available production accounting statistics. Data on actual fuel purchases were obtained for all major consumers of purchased fuel gas (e.g., full scale thermal recovery projects), and estimates based on extrapolations of available survey results were prepared for all other facilities. No corrections were made to the fuel data to account for any fuel used for non-combustion purposes (e.g., purge gas, instrument gas, compressor start gas, and blanket gas). At each site total gas use was prorated to the actual or expected types of combustion sources (i.e., reciprocating engines, turbines, heater and boilers and incinerators). Fuel used to adjust the heating value of waste gas streams to allow stable flaring was not directly evaluated; rather, this portion of total fuel consumption was allocated proportionately to the other combustion source categories at each site. Site specific-fuel gas analyses were applied where available; otherwise, appropriate default values were used (see Volume 3).

• Flaring – a distinction was made between acid gas flaring and all other types of flaring. The gas

compositions were determined using either available site-specific data or typical default values by industry sector. The amount of both types of flaring was taken directly from the available production accounting statistics. No corrections were made to try to account for any gas volumes reported as flared but which are actually vented. Additionally, no corrections were made to account for leakage into flare systems.

• Formation CO2 Venting – is the atmospheric release of naturally or artificially occurring CO2

originally present in the produced oil and gas. Artificially occurring CO2 may result from enhanced recovery schemes such as CO2 miscible floods or fire floods.

• Reported Venting – accounts for vented volumes stated in production accounting statistics.

These volumes are assumed to comprise, where applicable, casing gas venting, waste associated gas flows, treater and stabilizer off-gas and gas volumes discharged during process upsets and equipment depressurization events. Storage and loading/unloading losses are assumed to be generally excluded from reported vented volumes, and, therefore, are assessed separately.

• Unreported Venting – is the sum of all miscellaneous vented volumes not normally included in

reported vented volumes and not otherwise accounted for in the developed emissions inventory. This may include instrument vent gas, compressor start gas, purge gas and blanket gas that is discharged directly to the atmosphere, and dehydrator still column off-gas.

• Fugitive Equipment Leaks – are the loss of hydrocarbon gas and liquids to the atmosphere

past mechanical connections, seals and valve seats due to normal wear and inefficiencies in these mechanisms.

16

• Storage Losses – comprise normal evaporation losses due to breathing and working effects,

plus flashing losses where the received liquids have an initial vapour pressure close to or greater than local atmospheric pressure. Gas carry-through to storage tanks due to leakage past drain valves into tank inlet headers, inefficient gas-liquid separation in upstream vessels, malfunctioning level controllers or leakage past the seat of level control valves, or unintentional storage of high vapour pressure liquids in atmospheric tanks are known to be a noteworthy source at some sites, but could not be accounted for due to a lack of appropriate emission factors.

• Loading/Unloading Losses – are evaporation losses to the atmosphere that result from the

exposure and agitation of hydrocarbon liquids during loading and/or unloading activities. • Accidental Releases – are unintentional releases of gases and unrecovered hydrocarbon liquids

to the environment due to spills and major equipment failures (e.g., pipeline ruptures, third party dig-ins, well blow-outs, gas migration around the outside of well casings and surface casing vent flows).

17

4.0 OVERVIEW OF RESULTS The GHG emission inventory is compiled in an Access database which contains the facility level emissions detail for each UOG facility in Canada. The database contains some 1.6 million records and provides the GHG emission details for over 210 000 facilities ranging is size from individual wells to large gas processing plants and thermal heavy oil operations. For each facility, emissions from each applicable source category and for each of the greenhouse gases are provided. A summary of the information in the database is presented in the sections that follow. In general, the discussion is limited to the subject portion of the UOG. That is, the gas transmission, storage and distribution portions are not included in the following sections. 4.1 CO2 Equivalent Emissions Total CO2E GHG emissions by the UOG industry in Canada in 2000 are estimated at 84 355 kilotonnes (kt) with an uncertainty of ±1.5 %. This amounts to 12 percent of Canada’s total (net) national emissions of GHGs in 2000. The contribution by gas to total emissions is 44 866 kt CO2 (53.2 percent CO2E), 1 849 kt CH4 (46.0 percent CO2E) and 2.1 kt from N2O (0.8 percent CO2E). The atmospheric oxidation of all non-CO2 carbon-containing gases (e.g., as CO or THC) contributes a further 7 234 kt of CO2 equivalent. (This amount excludes atmospheric oxidation already accounted for in the applied emission factors for fuel combustion - see Section 2.8 of Volume 3). A breakdown of the CO2 equivalent contribution by sub-sector and province or territory is presented in Table 2. The uncertainty bounds for each emission estimate, expressed as percentages of the emission value, are presented in brackets below the emission estimate. Similar tabular summaries of these emissions for each year in the time series 1990 to 2000 are presented in the Appendix I. As shown in Figure 5, the CO2 equivalent GHG emissions are primarily from gas production (24.0 percent), heavy oil and cold bitumen production (22.1 percent), sour gas processing by plants with sulphur recovery (14.4 percent), light and medium crude oil production (11.9 percent), and thermal heavy oil and bitumen production (8.5 percent). Most of the rest is from other types of gas processing facilities (i.e., sour with flaring or injection of acid gas, sweet and straddle plants) (10.8 percent), accidental releases (5.0 percent) and drilling activities (1.5 percent), with the remainder (1.8 percent) coming from a number of lesser sources. The larger contributors are generally the greatest consumers of fuel. It is interesting to note that collectively, natural gas production and processing facilities contribute nearly one-half of the total CO2 equivalent GHG emissions by the UOG industry. Contributions by gas transmission and distribution systems are not included in these totals but are reported in the appendices. The greatest primary source of the estimated CO2 equivalent emissions is fuel combustion, which accounts for 40.8 percent of the total, followed by reported venting (15.7 percent), fugitive equipment leaks (11.9 percent), unreported venting (11.4 percent), releases of formation CO2 (8.1

18

percent), flaring (6.2 percent), accidental releases (5.0 percent), storage losses (1.0 percent), and loading/unloading losses (less than 0.01 percent) (see Figure 5). 4.2 CO2 Emissions The UOG industry emitted 44 866 kt of CO2 in 2000 (see Figure 6). Natural gas production and processing contributes almost two-thirds of CO2 emissions by the UOG industry. Roughly three quarters of the CO2 emissions are from fuel combustion, with nearly all the rest coming almost equally from flaring and releases of formation CO2. 4.3 CH4 Emissions The CH4 emissions amounted to 1 849 kt (see Figure 7) or about 1.25 percent of total natural gas production in Canada in 2000. These emissions are primarily contributed by heavy oil and cold bitumen production (42.0 percent), gas production (27.6 percent), light and medium crude oil production (13.3 percent) and accidental releases (10.7 percent) (see Figure 7). The rest (6.4 percent) is mostly from natural gas processing facilities and thermal heavy oil and crude bitumen production. Venting is the main source of CH4 emissions, accounting for almost two-thirds (58.3 percent total; 33.6 percent reported venting and 24.7 percent unreported venting) of the total. The other sources are, in the order of decreasing magnitude: fugitive equipment leaks (25.8 percent) and accidental releases (10.7 percent), incomplete fuel and waste gas combustion (3.1 percent), and evaporation losses due to product storage and handling (2.2 percent). 4.4 N2O Emissions Nitrous oxide emissions are estimated at 2.1 kt (see Figure 8) and are attributed exclusively to fuel and waste gas combustion activities, with fuel combustion contributing virtually all of this amount. Most of the N2O emissions are from gas production (40.8 percent), followed by gas processing (33.0 percent), light and medium crude oil production (9.8 percent), drilling (5.3 percent), heavy oil and cold bitumen production (4.8 percent), thermal heavy oil and bitumen production (4.5 percent), and well servicing (1.8 percent). 4.5 CO2 Atmospheric Oxidation Emissions The atmospheric oxidation of all non-CO2 carbon-containing gases emitted by sources other than fuel combustion amount to 7 234 kt of CO2 atmospheric oxidation. Atmospheric oxidation of non-CO2 carbon-containing gases emitted as products of incomplete fuel combustion is already accounted for in the reported CO2 emissions from fuel combustion. A breakdown of the non-fuel related contribution by type of source is provided in Figure 9. Venting is the greatest source, accounting for almost one-half (49.5 percent) of the total. Equipment leaks, accidental releases and storage losses contribute 26.2, 14.0 and 9.7 percent, respectively.

19

Table 2. GHG Emissions For Year 2000 From Subject Oil and Gas Activity by Province/Territory

GHG Emissions (kt CO2 E) [Uncertainties are in percent] Sector NWT YK BC AB SK MB ON NS NL Total

Well Drilling 4.2 (-12.6;+12.6)

242.0 (-2.1;+2.1)

892.2 (-0.6;+0.6)

125.3 (-0.8;+0.8)

11.2 (-31.3;+31.3)

22.2 (-5.0;+5.0)

4.1 (-14.4;+14.4)

0.3 (-33.1;+33.1)

1 301 (-0.6;+0.6)

Well Servicing 0.5 (-16.3;+16.3)

15.1 (-5.3;+5.3)

407.2 (-5.4;+5.4)

114.0 (-12.0;+12.0)

1.7 (-19.4;+19.4)

2.6 (-17.9;+17.9)

0.1 (-10.1;+10.1)

541 (-4.8;+4.8)

Well Testing 203.1 (-3.5;+3.5)

778.2 (-6.5;+6.0)

981.3 (-5.3;+4.8)


184.7 (-21.7;+21.8)

845.1 (-2.0;+2.7)

6 799 (-0.9;+1.0)

1 481 (-2.6;+2.8)

58.1(-5.1;+7.8)

38.8 (-35.0;+123)

596.6 (-14.4;+14.5)

10 004 (-1.2;+1.4)

Heavy Crude Oil Cold Production

9 156 (-3.1;+3.1)

9 509 (-3.6;+3.2)

18 665 (-2.4;+2.2)

Heavy Crude Oil Thermal Production

6 330 (-9.0;+9.0)

826.0 (-16.8;+16.8)

7 156 (-8.3;+8.2)


1.5 (-40.4;+81.7)

1 948 (-1.9;+2.3)

17 097 (-0.6;+0.8)

1 139 (-2.4;+3.3)

14.4 (-10.1;+22.4)

76.0 (-15.9;+13.0)

20 276 (-0.6;+0.8)

Natural Gas Processing – Sweet

294.9 (-5.3;+5.6)

3 520 (-1.6;+1.6)

47.9 (-10.3;+10.6)

2.2 (-20.0;+19.6)

224.3 (-16.9;+14.6)

4 088 (-1.7;+1.7)

Natural Gas Processing – Injection

244.0 (-5.5;+6.2)

802.3 (-5.8;+5.5)

1 046 (-4.6;+4.5)

Natural Gas Processing – Flaring

13.7 (-22.8;+21.5)

51.3 (-11.8;+15.0)

2 696 (-1.5;+1.7)

69.4 (-12.1;+11.3)

1.5 (-25.0;+156)

2 832 (-1.5;+1.6)

Natural Gas Processing – Sulphur Recovery

3 148 (-3.8;+3.8)

8 989 (-1.9;+1.9)

12 137 (-1.7;+1.7)

Natural Gas Processing – Straddle

1 097 (-8.3;+7.0)

1 097 (-8.3;+7.0)


0.8 (-22.0;+22.0)

24.9 (-19.7;+19.9)

7.7 (-40.4;+40.4)

0.4 (-37.9;+37.9)

1.2 (-38.1;+38.1)

34.9 (-16.7;+16.8)

Accidents/ Equipment Failures

0.1 (-36.7;+36.7)

0.1 (-42.9;+42.9)

103.3 (-1.3;+1.3)

2 685 (-31.1;+31.1)

1 306 (-42.2;+42.2)

52.4 (-42.9;+42.9)

49.9 (-42.9;+42.9)

0.2 (-42.9;+42.9)

0.0 (-38.1;+38.1)

4 197 (-23.9;+23.9)

Total 189.4 (-21.1;+21.3)

15.4 (-20.8;+20.8)

7 095 (-1.8;+1.9)

61 274 (-1.8;+1.8)

14 624 (-4.6;+4.4)

123.8 (-18.5;+18.7)

132.8 (-19.2;+39.5)

304.7 (-13.1;+11.3)

596.6 (-14.4;+14.5)

85 355 (-1.5;+1.5)

20

Carbon Dioxide Equivalent Emissions Presented by Sector Total Emissions = 84 355 kt/y

Product Transportation0.04%

Thermal Operations8.48%

Well Servicing0.64%

Well Testing1.16%

Light/Medium Crude Oil11.86%

Heavy Oil/Cold Bitumen22.13%

Gas Production24.04%

Drilling1.54%

Gas Processing - Flaring3.36%

Gas Processing - Straddle1.30%

Gas Processing - Injection1.24%

Gas Processing - Sulphur Recovery

14.39%

Gas Processing - Sweet4.85%

Accidents and Equipment Failures4.98%

Carbon Dioxide Equivalent Emissions Presented by Source Category Total Emissions = 84 355 kt/y

Fuel Combustion40.82%

Loading/Unloading0.01%


Unreported Venting11.36%

Storage Losses1.01%

Flaring6.18%

Formation CO28.08%

Reported Venting15.67%

Fugitive Equipment Leaks11.90%

Figure 5. Pie charts depicting the percentage contributions, by sector and source category, to

total CO2 equivalent emissions by the UOG industry in 2000.

21

Carbon Dioxide Emissions Presented by Sector Total Emissions = 44 866 kt/y



Well Servicing0.69%

Well Testing1.96%


Heavy Oil/Cold Bitumen5.17% Gas Production

20.72%

Drilling2.80%





26.58%



Carbon Dioxide Emissions Presented by Source Category Total Emissions = 44 866 kt/y





Storage Losses0.01%

Flaring10.99%

Formation CO215.19%




total CO2 emissions by the UOG industry in 2000.

22

Methane Emissions Presented by Sector Total Emissions = 1 849 kt/y




Well Servicing0.57%

Well Testing0.27%




0.42%




Drilling0.03%



Methane Emissions Presented by Source Category Total Emissions = 1 849 kt/y





Flaring0.73%


Storage Losses2.19%



total CH4 emissions by the UOG industry in 2000.

23

Nitrous Oxide Emissions Presented by Sector Total Emissions = 2.13 kt/y







7.47%




Drilling5.33%


Well Testing0.00%

Well Servicing1.78%

Nitrous Oxide Emissions Presented by Source Category Total Emissions = 2.13 kt/y

Flaring0.00%



total N2O emissions by the UOG industry in 2000.

24

CO2 Atmospheric Oxidation Emissions Presented by Sector Total Emissions = 7 234 kt/y



Well Testing0.19%




Drilling0.02%





0.26%



CO2 Atmospheric Oxidation Emissions Presented by Source Category Total Emissions = 7 234 kt/y




Formation CO20.00%Accidents and Equipment

Failures13.97%

Storage Losses9.67%



total CO2 emissions from atmospheric oxidation of carbon substances emitted by the UOG industry in 2000.

25

5.0 COMPARISONS WITH OTHER INVENTORIES To give some perspective and provide some verification of the developed inventory, it is appropriate to compare the compiled results with those from other related inventories. Since the last update of CAPP’s CH4 and VOC emissions inventory (CAPP, 1999) for 1995 activity data, no further work has been done to update the emission estimates. CAPP 1999 has been used extensively for estimating UOG GHG emissions, including by Environment Canada as a source document for Canada’s National GHG Inventory. It is appropriate, therefore, to compare the current results with the 1995 inventory results. Table 3 below provides such a comparison. 5.1 Comparison with the CAPP 1995 Inventory In absolute terms, GHG emissions increased between 1995 and 2000, the base year of the current inventory. This is predominantly because of the growth in industry production over that period. Emissions for several provinces are significantly different than was estimated in the 1995 inventory. Newfoundland had no oil or gas production in 1995; the Hibernia began production in 1998. Nova Scotia’s upstream oil and gas industry switched from being all oil production over the period of 1992 to 1999, to being all gas production and processing in 2000. Emissions from oil and gas operations in the Northwest Territories, Yukon Territory, Ontario and Nova Scotia had all been estimated based on total provincial oil and gas production, and some simple production based emission factors derived from Alberta data. Each of these provinces/territories has a relatively small number of producing facilities with relatively high production. As a result, emissions from these areas tended to be over-estimated in the 1995 inventory. In the case of the Yukon, by a significant amount. In the present inventory, actual infrastructure data and production and disposition data were used to estimate emissions for these areas, and the estimated emissions are expected to be more representative. Emissions of N2O have increased by about 42.4 percent from 1995 to 2000, while national fuel consumption by the industry increased by 23 percent. Based on the detailed information available from the industry survey, the disposition of fuel to heaters/boilers, reciprocating engines and gas turbines is weighted more toward reciprocating engines than had previously been estimated. Since reciprocating engines emit significantly more N2O than heaters/boilers (i.e., about 6 times as much N2O), the estimated N2O emissions are proportionately larger per unit of fuel burned. CO2 is emitted predominantly by combustion of fuel and waste gas. Between 1995 and 2000, the total volume of natural gas fuel burned and waste gas flared increased by 17.4 percent. During this same time period CO2 emissions increased by approximately the same percentage, from 38 743 kt to 44 866 kt (or 15.8 percent), well within the uncertainty bounds on the 2000 estimate. CH4 emissions increased by 38 percent between 1995 and 2000. The corresponding increases in overall production and fuel/flare volumes were 11.9 percent and 17.4 percent, respectively. The increase may be attributed to:

• Increased venting from some heavy oil operations.

26

• The revised fuel gas disposition towards reciprocating engines that have significantly higher methane emissions. Reciprocating engines have methane emissions that are typically two orders of magnitude greater than those for heaters/boilers.

• As the industry ages, the amount of process infrastructure compared to the amount of production will tend to increase. For example, light/medium oil production is declining but the number of producing facilities is actually increasing.

27

Table 3. Comparison GHG Emissions For Year 2000 From Subject Oil and Gas Activities by Province/Territory For Years 1995 and 2000

1995 GHG Emissions (kt/y) 2000 GHG Emissions (kt/y) Province

CO2 CH4 N2O CO2 Equivalent CO2 CH4 N2O CO2

Equivalent NWT 21.78 2.45 0.002 73.6 185.6

(-21.6; +21.6) 0.111

(-13.4; +57.1)0.005

(-26.5; +328)189.4

(-21.1; +21.3)Yukon 64.12 2.31 0.005 114.2 13.2

(-23.7; +18.2) 0.088

(-35.8; +68.9)0.001

(-35.7; +528)15.4

(-20.8; +20.8)British Columbia 5 101 51.7 0.109 6 221 5 807

(-2.2; +2.2) 58.0

(-1.2; +2.8)0.228

(-2.2; +36.5)7 095

(-1.8; +1.9)Alberta 30 282 990.6 1.25 51 471 35 386

(-1.7; +1.7) 1 207

(-3.5; +3.5)1.757

(-1.1; +17.1)61 274

(-1.8; +1.8)Saskatchewan 3 150 281.5 0.122 9 098 2 560

(-3.5; +3.3) 572.9

(-5.5; +5.3)0.108

(-3.8; +52.0)14 624

(-4.5; +4.4)Manitoba 42.7 3.57 0.002 118.2 48.9

(-9.2; +9.2) 3.54

(-30.2; +30.6)0.002

(-23.9; +43.5)123.8

(-18.5; +18.7)Ontario 81.7 5.09 0.004 189.7 29.4

(-5.9; +5.9) 4.89

(-24.7; +51.1)0.002

(-8.2; +20.7)132.7

(-19.2; +39.5)Nova Scotia 0.024 0.270 0.000 5.70 263.1

(-15.0; +11.6) 1.74

(-15.6; +11.6)0.016

(-18.8; +297)304.7

(-13.1; +11.3)Newfoundland ---- ---- ---- ---- 573.0

(-14.9; +14.9) 1.02

(-53.0; +58.1)0.008

(-24.8; +370)596.9

(-14.4; +14.5)Canada 38 743 1 337 1.494 67 292 44 866

(-1.4; +1.4) 1 849

(-2.9; +2.8)2.128

(-1.0; +15.2)84 355

(-1.5; +1.5)

28

6.0 EMISSION INTENSITY ANALYSIS An analysis was undertaken at the facility level to try and devise simple correlations or relationships that could be used to determine reasonable emission intensity benchmarks for individual facilities according to their type and specific circumstances (e.g., age, inlet pressure, inlet gas, hydrocarbon liquid and water production, contaminant concentrations and products produced. This work, which is still in progress, has comprised an iterative process involving industry experts from a broad cross-section of the UOG industry, as well as representatives from Natural Resources Canada. The initial approach involved trying to correlate intensities to a rational selection of readily available parameters or indices using optimization techniques and a large array of arbitrary functional forms; the aim was to find the best fit correlation. The results suggest that many good correlations exist, but none which provide reasonable results across the full range of facilities in each category. The observed weaknesses in the developed correlations were ultimately attributed to the lack of sound underlying engineering principles or a physical basis. Accordingly, the approach adopted for this analysis consists of identify the available parameters that correlate most strongly with emission intensities, and then developing simple computer models based on the use of these parameters and basic mass, energy and thermodynamic principles. This approach has been applied to natural gas processing plants, and is now being applied to other types of facilities. In the case of natural gas processing plants, the correlation between GHG emissions estimated by the engineering model and inventory data is very good (i.e., an R2 of approximately 0.98). The complexity of the overall problem is illustrated in the graphs presented in Appendix III, which plot cumulative GHG emissions as a function of cumulative production for different types of facilities. A vertical line is drawn through each data point to depict the associated confidence interval for each point. To provide some high level means of assessing GHG emissions from the UOG sector knowing only a limited amount of activity data a series of emission intensity factors have been developed (see Table 4). The factors are simply total emissions for the sub-sector divided by an appropriate activity value. The activity values used are:

• Wells Drilled – number of wells drilled (20 566), • Well Servicing – number of wells drilled (20 566), • Well Testing – number of wells drilled (20 566), • Light/Medium Crude Oil Production – light/medium oil produced (55 588 × 103 m3), • Heavy Crude Oil Cold Production – primary/secondary heavy oil + cold bitumen

production (30 924 × 103 m3), • Heavy Crude Oil Thermal Production – thermal heavy oil/bitumen production (10 589 ×

103 m3), • Natural Gas Production – raw natural gas produced (217 558 × 106 m3), • Natural gas Processing – raw natural gas produced (217 558 × 106 m3),

29

• Petroleum Liquids Production – total light/medium + heavy oil + bitumen produced (97 101 × 103 m3), and

• Accidents/Equipment Failures – total oil and gas production as an oil equivalent (311 955 × 103 m3).

Since all emissions within the sub-sector may not be well correlated with the selected denominator, care must be taken in applying these emission intensity factors. In addition, the uncertainties associated with the resulting emission estimates will necessarily be much greater than those associated with the detailed emission inventory estimates.

30

Table 4. Summary of emission intensity factors presented by sub-sector of the UOG sector for 2000.

Emission Intensity Factor (t/quantity) [uncertainty in emission estimates are in percent] Activity Denominator Used CO2 CH4 N2O CO2E CO2O NMVOC

Well Drilling Wells Drilled

61.1 0.023 0.0055 63.3 0.053 0.076

Well Servicing Wells Drilled

15.0 0.51 0.0018 26.3 ---- 0.11

Well Testing Wells Drilled

42.7 0.24 ---- 47.7 0.68 0.056


Light/Medium Oil Produced (103 m3)

86.3 4.41 0.0038 180.0 26.6 4.94

Heavy Crude Oil Cold Production

Primary/Secondary Heavy Oil + Cold Bitumen Produced (103 m3)

75.0 25.1 0.0033 603.6 85.9 5.70

Heavy Crude Oil Thermal Production

Thermal Bitumen Produced (103 m3)

594.2 3.75 0.0090 675.8 13.5 1.15


Natural Gas Produced (106 m3)

42.7 2.34 0.0040 93.2 7.83 0.59


Natural Gas Produced (106 m3)

90.4 0.29 0.0032 97.4 0.87 0.14


Light/Medium + Heavy + Bitumen Produced (103 m3)

0.092 0.013 ----

0.36 0.41 0.13

Accidents/Equipment Failures

All Natural Gas and Oil Produced (103 m3 OE)

0.12 0.63 ---- 13.5 3.24 0.48

31

7.0 CONCLUSIONS AND RECOMMENDATIONS 7.1 Conclusions The major conclusions of this study are:

• In 2000, the UOG industry in Canada emitted an estimated 84 355 kt of CO2 equivalent GHGs. The source of almost half of this (40.8 percent) was fuel combustion, followed by venting (27.1 percent), fugitive equipment leaks (11.9 percent), formation CO2 releases (8.1 percent), flaring (6.2 percent), accidental releases (5.0 percent), and storage and handling losses (1.0 percent). The estimated uncertainty in these emissions is ±1.5 percent. Atmospheric oxidation of non-CO2 carbon-containing gaseous emissions (i.e., CO and NMHC) contributes an additional 7 234 kt of CO2E.

• In 2000, Alberta, Saskatchewan and British Columbia collectively accounted for over 89

percent of Canada’s total oil production and 96 percent of its natural gas production. The remaining production was from Ontario, Manitoba, the Northwest Territories, Nova Scotia, Newfoundland and the Yukon. The associated emissions of GHGs were generally distributed in similar proportions.

• Looking ahead, the areas where oil and gas GHG emissions may be expected to increase

and to decrease over time are:

Increases • Increased processing energy is required as more water is produced along with oil. • Increased compression is required as reservoir pressures decline. • The tendency toward frontier gas production will require additional energy to

transport the product to market. • Hydrogen sulphide and carbon dioxide concentrations in newly discovered gas

pools tend to be increasing, which will increase processing energy requirements and formation CO2 emissions.

• The tendency toward heavy oil and bitumen production as light/medium oil reserves decline may result in increased emissions.

• Heavy oil gas-to-oil ratios (GORs) appear to be increasing as technology has been developed to produce from high GOR pools.

Decreases

• Flaring of solution gas has decreased (especially in Alberta) since the implementation of EUB G-60. From implementation in 1999 the G-60 requirements have resulted in a 62 percent reduction in solution gas flaring (to 2002, the last year for which statistics are available).

• Additional regulations aimed at reducing vented gas have recently been instituted. This is expected to reduce vent gas volumes over the next few years.

• If gas prices remain high, more gas conservation schemes will be economically viable, and flared and vented gas volumes will tend to decrease.

32

8.0 REFERENCES CITED Alberta Energy and Utilities Board. 2000. Alberta Energy Resource Monthly Statistics. ST 3-2000. British Columbia Oil and Gas Commission. British Columbia Annual Oil and Gas Statistics - 1966 to 2001. Available on the website: http://www.ogc.gov.bc.ca CAPP (Canadian Association of Petroleum Producers). 1999. A Detailed Inventory of CH4 and VOC Emissions from Upstream Oil and Gas Operations in Canada, CAPP Pub. # 1999-0010. Calgary, AB. CGA (Canadian Gas Association). 2004. Provincial Disaggregation of 2000 Greenhouse Gas Inventory for Canadian Gas Transmission, Storage and Distribution Sectors. Unpublished data. Guelph, ON. ICF Consulting Canada Inc. 2000. Canadian Natural Gas Companies 2000 Greenhouse Gas Inventory Report and Validation by Audit. Toronto, ON. Intergovernmental Panel on Climate Change (IPCC). 1996. Greenhouse Gas Inventory Reference Manual: IPCC Guidelines for National Greenhouse Gas Inventories, Volumes 1 to 3, United Nations Environment Programme, the Organization for Economic Co-operation and Development, the International Energy Agency, and the Intergovernmental Panel on Climate Change. http://www.ipcc-wg2.org/index.html IPCC (Intergovernmental Panel on Climate Change). 2000. IPCC Good Practice Guidance and Uncertainty Management in National Greenhouse Gas Inventories, May 2000. http://www.ipcc-wg2.org/index.html Manitoba Industry, Trade and Mines. 2000 Manitoba Oil Activity Review. Available on the website: www.gov.mb.ca/itm/petroleum/oar/index.html Ontario Oil, Gas & Salt Resources Library. Database available at: www.ogsrlibrary.com Saskatchewan Industry and Resources. 2000. Mineral Statistics Yearbook 2000. Miscellaneous Report 2000-3. Statistics Canada. 2000. Supply and Disposition of Crude Oil and Natural Gas. Catalogue No. 26-006-XPB. UNFCCC (United Nations Framework Convention on Climate Change). 2002. Report of the Conference of the Parties on its eighth session, held at New Delhi from 23 October to 1 November 2002, Guidelines for the preparation of national communications by Parties included in Annex I to the Convention, part I: UNFCCC reporting guidelines on annual inventories, Decision /CP.8, 2002. http://unfccc.int/cop8/latest/5_sbstal5add1.pdf

33

9.0 APPENDIX A: TABULAR SUMMARY OF EMISSIONS FOR YEAR 2000 Table A, which follows, provides a summary of greenhouse gas emissions presented by sub-sector, facility type and sub-type and emission source. Table A is made up four separate tables, one for each of the main greenhouse gases – CO2, CH4, N2O and CO2E. Sub-sector production and facility counts are also included.

34



Activity Type Production Units Facility Type Facility Sub-Type (or activity sub-type) Facility

Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported

Fugitives: EquipmentAnd Other

Total

(drilling) 20 566 wells drilled 1 285 1 285 Well (drill-stem testing) 20 566 wells drilled 10 7 16

Well Drilling N/A N/A

Sub Total All 1 285 10 7 1 301 (service rigs) 1 710 405 rig hours 144 144 (pumping units) 1 710 405 rig hours 177 177

Well

(blowdown treatments) 220 220

Well Servicing

N/A N/A

Sub Total All 321 220 541 Well (well testing) N/A 890 92 981 Well Tests N/A N/A Sub Total All 890 92 981

L/M Crude Oil – Flowing 3 454 wells 1 2 1 4 Well L/M Crude Oil – Pumping 56 175 wells 4 5 12 20 Crude Oil – Single 5 817 facilities 291 681 439 1 226 1 024 3 661 Crude Oil – Satellite 1 153 facilities 1 347 630 351 553 618 3 499

Battery

Crude Oil – Group 1 371 facilities 974 1 010 59 453 324 2 819 Disposal Water 1 868 wells 1 1


55 588 103 m3/y

Sub Total All 2 617 2 320 850 2 238 1 979 10 004 Heavy Crude Oil – Primary/Secondary 30 082 wells 2 022 848 2 870

Well

Oil Sands - Cold 5 868 wells 301 94 394 Crude Bitumen – Single 5 282 facilities 179 121 2 689 395 386 3 770 Crude Bitumen – Satellite 378 facilities 632 331 681 352 235 2 230 Crude Bitumen – Group 19 facilities 544 100 4 945 188 121 5 899 Oil Sands – Single 1 689 facilities 86 82 1 919 56 32 2 176 Oil Sands – Satellite 265 facilities 31 26 740 12 32 840

Battery

Oil Sands – Group 152 facilities 31 43 355 4 52 486


30 924 103 m3/y

Sub Total All 1 504 703 11 329 3 330 1 799 18 665 Heavy Crude Oil - Thermal 134 wells negl. negl. Well Oil Sands - Thermal 2 450 wells negl. negl. Crude Bitumen - Group 7 facilities 402 18 374 27 5 826 Battery Oil Sands - Group 8 facilities 5 639 267 415 2 6 6 329

Disposal Water 69 wells negl. negl.


10 589 103 m3/y

Sub Total All 6 042 285 789 29 11 7 156 Natural Gas – Shallow – All 63 693 wells 3 31 160 194 Natural Gas – Deep – Sweet 32 282 wells 39 144 139 322

Well

Natural Gas – Deep – Sour 2 952 wells 23 6 8 36 Gathering System 2 171 facilities 6 168 132 896 1 467 8 662 Compressor Station 3 306 facilities 1 057 21 4 271 347 1 700 Meter Station 2 172 facilities 35 94 129 Meter/Regulation Station 431 facilities 2 17 19

Gathering System

Regulator Station 4 745 facilities 3 36 39 Natural Gas – Single 1 936 facilities 168 25 8 1 020 1 076 2 297 Battery Natural Gas – Group 3 728 facilities 2 233 78 144 2 269 2 152 6 876

Disposal Gas Injection 905 wells 1 1


217 558 106 m3/y

Sub Total 9 690 255 157 4 677 5 497 20 276 Sweet Natural Gas Plant

All 429 facilities 3 320 116 8 68 575 4 088 Sour Natural Gas Plant – Acid Gas Flaring

All 144 facilities

1 944 128 649 35 76 2 832 Sour Natural Gas Plant – Acid Gas Injection

All 60 facilities

954 61 10 21 1 046 Sour Natural Gas Plant – Sulphur Recovery

All 56 facilities

5 696 207 6 155 23 55 12 137


171 580 106 m3/y

Straddle Natural Gas All 7 facilities 1 058 12 4 23 1 097

35




Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total

Plant Sub Total All 12 973 524 6 805 139 750 21 199 Natural Gas Transmission

All Not Available facilities 12 286 1 308 1 969 15 563 Natural Gas Distribution

All Not Available facilities 81 96 988 1 165 Storage as Natural Gas

All Not Available facilities 36 13 65 113 Storage as LNG All Not Available facilities 6 3 7 15


171 584 106 m3/y

Sub Total All 12 409 1 420 3 028 16 857 All All 9 negl. negl. 9 Pump Station All 334 facilities 2 negl. 2

Pipeline Terminal 576 tanks 19 negl. 19 Production Tank 334 tanks 4 negl. 4

Storage

Tank Farm 105 tanks 1 negl. 1


97 100

103 m3/y light +

medium + heavy

Sub Total All 9 26 negl. 35 All (natural gas migration) N/A N/A 42 42 All (pipeline ruptures) N/A N/A 834 834 All (spills) N/A N/A 5 5 All (surface casing vent flows) N/A N/A 3 217 3 217

Accidents and Equipment Failures (unallocated) N/A N/A

Sub Total All 4 197 4 197 Total All All 46 840 5 216 6 805 14 636 10 445 17 262 101 211

36

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (kt CO2)



Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total

(drilling) 20 566 wells drilled 1 247 1 247 Well (drill-stem testing) 20 566 wells drilled 10 negl. 10


Sub Total All 1 247 10 negl. 1 247 (service rigs) 1 710 405 rig hours 140 140 (pumping units) 1 710 405 rig hours 169 169

Well

(blowdown treatments) negl. negl.

Well Servicing

N/A N/A

Sub Total All 308 negl. 308 Well (well testing) N/A 878 negl. 878 Well Tests N/A N/A Sub Total All 878 negl. 878

L/M Crude Oil – Flowing 3 454 wells 1 negl. negl. 1 Well L/M Crude Oil – Pumping 56 175 wells 4 negl. negl. 4 Crude Oil – Single 5 817 facilities 284 672 3 1 7 968 Crude Oil – Satellite 1 153 facilities 1 260 622 2 1 3 1 866

Battery

Crude Oil – Group 1 371 facilities 935 997 1 1 2 1 935 Disposal Water 1 868 wells negl. negl.


55 588 103 m3/y

Sub Total All 2 484 2 291 5 3 12 4 795 Heavy Crude Oil – Primary/Secondary 30 082 wells 2 negl. 2

Well

Oil Sands - Cold 5 868 wells negl. 5 5 Crude Bitumen – Single 5 282 facilities 176 120 negl. 1 negl. 298 Crude Bitumen – Satellite 378 facilities 594 326 negl. 1 negl. 922 Crude Bitumen – Group 19 facilities 535 98 1 negl. negl. 635 Oil Sands – Single 1 689 facilities 80 82 106 2 1 271 Oil Sands – Satellite 265 facilities 29 25 39 negl. 1 95

Battery

Oil Sands – Group 152 facilities 29 42 18 negl. 2 92


30 924 103 m3/y

Sub Total All 1 445 694 164 6 11 2 320 Heavy Crude Oil - Thermal 134 wells negl. negl. Well Oil Sands - Thermal 2 450 wells negl. negl. Crude Bitumen - Group 7 facilities 399 18 negl. negl. negl. 417 Battery Oil Sands - Group 8 facilities 5 609 264 2 negl. negl. 5 875

Disposal Water 69 wells negl. negl.


10 589 103 m3/y

Sub Total All 6 008 282 2 negl. negl. 6 292 Natural Gas – Shallow – All 63 693 wells 3 negl. negl. 3 Natural Gas – Deep – Sweet 32 282 wells 35 negl. negl. 36

Well

Natural Gas – Deep – Sour 2 952 wells 20 negl. negl. 20 Gathering System 2 171 facilities 5 759 130 2 1 5 892 Compressor Station 3 306 facilities 938 20 negl. 1 negl. 1 004 Meter Station 2 172 facilities negl. negl. negl Meter/Regulation Station 431 facilities negl. negl. negl.

Gathering System

Regulator Station 4 745 facilities negl. negl. negl. Natural Gas – Single 1 936 facilities 156 25 negl. 1 2 184 Battery Natural Gas – Group 3 728 facilities 2 071 77 negl. 5 4 2 157

Disposal Gas Injection 905 wells negl. negl.


217 558 106 m3/y

Sub Total 9 028 252 negl. 10 8 9 298 Sweet Natural Gas Plant

All 429 facilities 3 071 115 8 negl. 1 3 195 Sour Natural Gas Plant – Acid Gas Flaring

All 144 facilities

1 777 126 649 negl. negl. 2 552 Sour Natural Gas Plant – Acid Gas Injection

All 60 facilities

893 60 negl. negl. 954


171 580 106 m3/y

Sour Natural Gas Plant –

All 56 facilities

5 565 204 6 155 negl. negl. 11 925

37

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (kt CO2)



Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total

Sulphur Recovery Straddle Natural Gas Plant

All 7 facilities 1 033 12 negl. negl. 1 045 Sub Total All 12 339 518 6 805 negl. negl. 19 638 Natural Gas Transmission

All Not Available facilities 12 011 1 negl. 12 012 Natural Gas Distribution

All Not Available facilities 81 negl. 2 83 Storage as Natural Gas

All Not Available facilities 35 negl. negl. 35 Storage as LNG All Not Available facilities 6 negl. negl. 6


171 584 106 m3/y

Sub Total All 12 132 1 2 12 136 All All 9 negl. negl. 9 Pump Station All 334 facilities negl. negl. negl.

Pipeline Terminal 576 tanks negl. negl. negl. Production Tank 334 tanks negl. negl. negl.

Storage

Tank Farm 105 tanks negl. negl. negl.


97 100

103 m3/y light +

medium + heavy

Sub Total All 9 negl. negl. 9 All (natural gas migration) N/A N/A negl. negl. All (pipeline ruptures) N/A N/A 8 8 All (spills) N/A N/A negl. negl. All (surface casing vent flows) N/A N/A 31 31


Sub Total All 39 39 Total All All 44 992 4 931 6 805 173 19 74 57 002

38

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (t CH4)



Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total

(drilling) 20 566 wells drilled 147 147 Well (drill-stem testing) 20 566 wells drilled 5 314 319


Sub Total All 17 5 314 466 (service rigs) 1 710 405 rig hours 17 17 (pumping units) 1 710 405 rig hours 32 32

Well

(blowdown treatments) 10 471 10 471

Well Servicing

N/A N/A

Sub Total All 49 10 471 10 520 Well (well testing) N/A 568 4 364 4 932 Well Tests N/A N/A Sub Total All 568 4 364 4 932

L/M Crude Oil – Flowing 3 454 wells negl. 74 55 129 Well L/M Crude Oil – Pumping 56 175 wells 7 216 546 770 Crude Oil – Single 5 817 facilities 109 409 20 785 58 319 48 422 128 044 Crude Oil – Satellite 1 153 facilities 2 267 380 16 654 26 287 29 302 74 891

Battery

Crude Oil – Group 1 371 facilities 848 615 2 763 21 548 15 331 41 105 Disposal Water 1 868 wells 27 27


55 588 103 m3/y

Sub Total All 3 232 1 403 40 203 106 444 93 683 244 965 Heavy Crude Oil – Primary/Secondary 30 082 wells 96 185 40 391 136 575

Well

Oil Sands - Cold 5 868 wells 14 304 4 222 18 526 Crude Bitumen – Single 5 282 facilities 37 80 128 028 18 762 18 354 165 261 Crude Bitumen – Satellite 378 facilities 898 215 32 421 16 719 11 155 61 408 Crude Bitumen – Group 19 facilities 129 65 235 441 8 953 5 757 250 345 Oil Sands – Single 1 689 facilities 147 39 86 326 2 593 1 463 90 568 Oil Sands – Satellite 265 facilities 45 13 33 380 557 1 440 35 435

Battery

Oil Sands – Group 152 facilities 49 20 16 063 205 2 387 18 724


30 924 103 m3/y

Sub Total All 1 304 432 531 659 158 277 85 169 776 841 Heavy Crude Oil - Thermal 134 wells negl. negl. Well Oil Sands - Thermal 2 450 wells 5 5 Crude Bitumen - Group 7 facilities 12 32 17 806 1 270 224 19 343 Battery Oil Sands - Group 8 facilities 156 172 19 639 113 269 20 349

Disposal Water 69 wells 5 5


10 589 103 m3/y

Sub Total All 204 168 37 445 1 383 502 39 702 Natural Gas – Shallow – All 63 693 wells 8 1 452 7 622 9 083 Natural Gas – Deep – Sweet 32 282 wells 95 6 848 6 623 13 565

Well

Natural Gas – Deep – Sour 2 952 wells 67 283 357 707 Gathering System 2 171 facilities 11 587 86 42 589 69 803 124 065 Compressor Station 3 306 facilities 2 160 13 194 12 886 16 502 31 755 Meter Station 2 172 facilities 1 647 4 490 6 137 Meter/Regulation Station 431 facilities 96 809 905

Gathering System

Regulator Station 4 745 facilities 132 1 731 1 863 Natural Gas – Single 1 936 facilities 302 16 399 48 512 51 125 100 355 Battery Natural Gas – Group 3 728 facilities 4 475 50 6 847 107 793 102 316 221 481

Disposal Gas Injection 905 wells 27 27


217 558 106 m3/y

Sub Total 18 694 166 7 440 222 237 261 406 509 943 Sweet Natural Gas Plant

All 429 facilities 7 583 75 3 232 27 337 38 227 Sour Natural Gas Plant – Acid Gas Flaring

All 144 facilities

5 891 82 1 648 3 627 11 248 Sour Natural Gas Plant – Acid Gas Injection

All 60 facilities

1 900 38 464 994 3 395


171 580 106 m3/y


All 56 facilities

3 892 134 1 067 2 617 7 710

39

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (t CH4)



Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total


All 7 facilities 552 8 163 1 090 1 812 Sub Total All 19 818 337 6 574 35 665 62 392 Natural Gas Transmission

All Not Available facilities 2 857 62 271 93 743 158 871 Natural Gas Distribution

All Not Available facilities 7 4 569 46 931 51 507 Storage as Natural Gas

All Not Available facilities 26 604 3 082 3 712 Storage as LNG All Not Available facilities 5 141 310 456


171 584 106 m3/y

Sub Total All 2 895 67 585 144 066 214 546 All All 5 9 negl. 14 Pump Station All 334 facilities 83 negl. 83

Pipeline Terminal 576 tanks 899 1 900 Production Tank 334 tanks 204 negl. 204

Storage

Tank Farm 105 tanks 33 negl. 33


97 100

103 m3/y light +

medium + heavy

Sub Total All 5 1 227 2 1 234 All (natural gas migration) N/A N/A 1 987 1 987 All (pipeline ruptures) N/A N/A 39 330 39 330 All (spills) N/A N/A 216 216 All (surface casing vent flows) N/A N/A 156 482 156 482


Sub Total All 198 015 198 015 Total All All 13 556 46 341 688 695 496 456 818 509 2 063 557

40

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (t N2O)



Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total

(drilling) 20 566 wells drilled 113 113 Well (drill-stem testing) 20 566 wells drilled


Sub Total All 113 113 (service rigs) 1 710 405 rig hours 13 13 (pumping units) 1 710 405 rig hours 25 25

Well

(blowdown treatments)

Well Servicing

N/A N/A

Sub Total All 38 38 Well (well testing) N/A Well Tests N/A N/A Sub Total All

L/M Crude Oil – Flowing 3 454 wells negl. negl. Well L/M Crude Oil – Pumping 56 175 wells negl. negl. Crude Oil – Single 5 817 facilities 13 13 Crude Oil – Satellite 1 153 facilities 129 129

Battery

Crude Oil – Group 1 371 facilities 66 66 Disposal Water 1 868 wells 27


55 588 103 m3/y

Sub Total All 208 208 Heavy Crude Oil – Primary/Secondary 30 082 wells

Well

Oil Sands - Cold 5 868 wells Crude Bitumen – Single 5 282 facilities 7 7 Crude Bitumen – Satellite 378 facilities 60 60 Crude Bitumen – Group 19 facilities 20 20 Oil Sands – Single 1 689 facilities 9 9 Oil Sands – Satellite 265 facilities 3 3

Battery

Oil Sands – Group 152 facilities 3 3


30 924 103 m3/y

Sub Total All 101 101 Heavy Crude Oil - Thermal 134 wells Well Oil Sands - Thermal 2 450 wells Crude Bitumen - Group 7 facilities 8 8 Battery Oil Sands - Group 8 facilities 87 87

Disposal Water 69 wells


10 589 103 m3/y

Sub Total All 95 95 Natural Gas – Shallow – All 63 693 wells negl. negl. Natural Gas – Deep – Sweet 32 282 wells 4 4

Well

Natural Gas – Deep – Sour 2 952 wells 2 707 Gathering System 2 171 facilities 534 534 Compressor Station 3 306 facilities 93 93 Meter Station 2 172 facilities Meter/Regulation Station 431 facilities

Gathering System

Regulator Station 4 745 facilities Natural Gas – Single 1 936 facilities 17 17 Battery Natural Gas – Group 3 728 facilities 218 218

Disposal Gas Injection 905 wells


217 558 106 m3/y

Sub Total 869 869 Sweet Natural Gas Plant

All 429 facilities 290 290 Sour Natural Gas Plant – Acid Gas Flaring

All 144 facilities

140 140 Sour Natural Gas Plant – Acid Gas Injection

All 60 facilities

69 69


171 580 106 m3/y


All 56 facilities

159 159

41

Table A: Greenhouse Gas Emissions For Year 2000 By Type of Activity, Facility and Emission Source (t N2O)



Count Units Fuel

Combustion

Flaring

Formation CO2

Releases

Venting: Reported

Venting: Unreported


Total


All 7 facilities 44 44 Sub Total All 702 702 Natural Gas Transmission

All Not Available facilities 690 690 Natural Gas Distribution

All Not Available facilities 1 1 Storage as Natural Gas

All Not Available facilities 2 2 Storage as LNG All Not Available facilities negl. negl.


171 584 106 m3/y

Sub Total All 693 693 All All Pump Station All 334 facilities

Pipeline Terminal 576 tanks Production Tank 334 tanks

Storage

Tank Farm 105 tanks


97 100

103 m3/y light +

medium + heavy

Sub Total All All (natural gas migration) N/A N/A All (pipeline ruptures) N/A N/A All (spills) N/A N/A All (surface casing vent flows) N/A N/A


Sub Total All Total All All 2 821 2 821

42

10.0 APPENDIX B: SUMMARY OF GHG EMISSIONS FROM GAS TRANSMISSION, STORAGE AND DISTRIBUTION

The provincial breakdown of GHG emissions from gas transmission, storage and distribution was provided by the Canadian Gas Association (CGA, 2004). These data are not included in the inventory database and are provided here for convenience. TABLE 10.1 British Columbia CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive 12,297 23 - 258,255 Vented 6,241 12 - 131,081 Combustion 1,278 1,425,400 34 1,462,941 TOTAL 19,817 1,425,435 34 1,852,278 TRANS-STRGE Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - LNG FACILITIES Fugitive 119 1 - 2,508 Vented 132 1 - 2,765 Combustion 0 729 0 736 TOTAL 251 731 0 6,009 DISTRIBUTION Fugitive 2,629 17 - 55,235 Vented 507 4 - 10,642 Combustion 6 17,726 0 17,962 TOTAL 3,142 17,746 0 83,838 GRAND TOTAL Fugitive 15,046 41 - 315,998 Vented 6,880 16 - 144,488 Combustion 1,285 1,443,855 35 1,481,639 TOTAL 23,210 1,443,912 35 1,942,125

43

TABLE 10.2 Alberta CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive

56,925 - - 1,195,415

Vented 3,240 1 - 68,049 Combustion

462 2,878,471 171 2,941,240

TOTAL 60,627 2,878,472 171

4,204,704

TRANS-STRGE Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - LNG FACILITIES Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - DISTRIBUTION Fugitive 12,164 908 - 256,350 Vented 768 0 - 16,126 Combustion 0 14,081 1 14,432 TOTAL 12,932 14,989 1 286,907 GRAND TOTAL Fugitive

69,088 908 - 1,451,765

Vented 4,008 1 - 84,174 Combustion

462 2,892,552 172 2,955,672

TOTAL 73,559 2,893,461 172

4,491,611

44

TABLE 10.3 Saskatchewan CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive 7,593 120 - 159,580 Vented 26,422 515 - 555,374 Combustion 947 2,734,349 178 2,809,304 TOTAL 34,962 2,734,985 178 3,524,258 TRANS-STRGE Fugitive 532 15 - 11,196 Vented 37 1 - 783 Combustion 15 1,640 1 2,113 TOTAL 584 1,656 1 14,092 LNG FACILITIES Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - DISTRIBUTION Fugitive 6,397 412 - 134,752 Vented 2,057 60 - 43,256 Combustion 0 11,078 0 11,144 TOTAL 8,454 11,549 0 189,152 GRAND TOTAL Fugitive 14,523 547 - 305,528 Vented 28,516 576 - 599,413 Combustion 962 2,747,067 178 2,822,561 TOTAL 44,001 2,748,190 178 3,727,502

45

TABLE 10.4 Manitoba CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive 1,097 - - 23,029 Vented 2,677 0 - 56,208 Combustion 25 957,539 60 976,703 TOTAL 3,798 957,539 60 1,055,940 TRANS-STRGE Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - LNG FACILITIES Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - DISTRIBUTION Fugitive 1,753 177 - 36,986 Vented 186 11 - 3,910 Combustion 0 798 0 801 TOTAL 1,939 987 0 41,698 GRAND TOTAL Fugitive 2,849 177 - 60,015 Vented 2,862 11 - 60,118 Combustion 25 958,338 60 977,504 TOTAL 5,736 958,526 60 1,097,637

46

TABLE 10.5 Ontario CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive 14,307 3 - 300,443 Vented 22,838 0 - 479,598 Combustion 144 3,968,652 244 4,047,468 TOTAL 37,289 3,968,655 244 4,827,510 TRANS-STRGE Fugitive 2,550 - - 53,540 Vented 567 - - 11,906 Combustion 11 32,985 1 33,628 TOTAL 3,128 32,985 1 99,074 LNG FACILITIES Fugitive 157 - - 3,296 Vented 9 - - 195 Combustion 5 3,286 0 3,539 TOTAL 171 3,286 0 7,030 DISTRIBUTION Fugitive 22,458 747 - 472,363 Vented 901 - - 18,917 Combustion 1 28,115 0 28,199 TOTAL 23,359 28,863 0 519,480 GRAND TOTAL Fugitive 39,471 750 - 829,643 Vented 24,315 0 - 510,616 Combustion 161 4,033,037 247 4,112,834 TOTAL 63,947 4,033,788 247 5,453,093

47

TABLE 10.6 Quebec CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive 1,524 0 - 32,003 Vented 853 0 - 17,921 Combustion 1 47,102 3 48,045 TOTAL 2,379 47,103 3 97,969 TRANS-STRGE Fugitive - - - - Vented - - - - Combustion - - - - TOTAL - - - - LNG FACILITIES Fugitive 34 - - 718 Vented 0 - - 2 Combustion 0 1,631 0 1,637 TOTAL 34 1,631 0 2,358 DISTRIBUTION Fugitive 1,530 123 - 32,243 Vented 150 - - 3,156 Combustion 0 8,900 - 8,904 TOTAL 1,680 9,023 - 44,304 GRAND TOTAL Fugitive 3,088 123 - 64,965 Vented 1,004 0 - 21,079 Combustion 1 57,633 3 58,586 TOTAL 4,093 57,756 3 144,630

48

TABLE 10.7 CANADA (Sum of Provincial #’s)

CH4 (tonnes) CO2 (tonnes) N2O (tonnes) CO2eq (tonnes) TRANSMISSION Fugitive 93,742 147 - 1,968,725 Vented 62,272 528 - 1,308,231 Combustion 2,857 12,011,513 691 12,285,701 TOTAL 158,871 12,012,188 691 15,562,658 TRANS-STRGE Fugitive 3,082 15 - 64,736 Vented 604 1 - 12,689 Combustion 26 34,625 2 35,741 TOTAL 3,712 34,641 2 113,166 LNG FACILITIES Fugitive 311 1 - 6,522 Vented 141 1 - 2,962 Combustion 5 5,646 1 5,912 TOTAL 457 5,648 1 15,396 DISTRIBUTION Fugitive 46,931 2,384 - 987,930 Vented 4,568 74 - 96,006 Combustion 7 80,697 2 81,442 TOTAL 51,506 83,156 2 1,165,379 GRAND TOTAL Fugitive 144,065 2,547 - 3,027,914 Vented 67,585 605 - 1,419,889 Combustion 2,896 12,132,481 695 12,408,797 TOTAL 214,546 12,135,634 695 16,856,599

49

11.0 APPENDIX C: HISTORICAL SUMMARY OF EMISSIONS BY PROVINCE/ TERRITORY

Historical summaries of GHG (CO2, CH4, N2O, CO2E, CO2AO and NMVOC) emissions by province for the years 1990 through 2000 are provided in Table 11.1. The years 1990 through 1999 have been extrapolated from the 2000 inventory results using annual industry activity level data (e.g., oil and gas production, provincial fuel and flare volumes, wells drilled, total capable wells, etc.) as follows:

• Well Drilling and Testing – total wells drilled each year in each province,

• Well Servicing – total wells drilled each year in each province,

• Fuel Consumption – annual reported fuel consumption each year in each province,

• Flaring – annual reported flared/waste gas volume each year in each province,

• Formation CO2 – total raw gas production for each year in each province,

• Gas Production – total raw gas production for each year in each province,

• Gas Processing – total raw gas production for each year in each province

• Light/Medium Oil Production – total light/medium oil produced in each province each year,

• Cold Heavy Oil Production – total cold heavy oil and bitumen produced in each province each year,

• Thermal Heavy Oil Production – total thermal heavy oil and bitumen produced in each province each year,

• Petroleum Product Transportation – total volume of all liquid products produced in each province each year,

• Surface Casing Vent Flows/Gas Migration – total number of capable wells in each province each year, and

• Accidents and Equipment Failures – total mass of product released via spills, pipeline ruptures and blowouts.

To try to account for declining light/medium oil production, the amount of process infrastructure is assumed to remain essentially constant as production volumes decrease. The increased energy consumption required to handle increasing water cuts and decreasing solution gas flaring are accounted for by the fuel consumption and flaring factors, respectively. Heavy oil production steadily increased over the period 1990 to 2000. Accordingly, the increase in process infrastructure is assumed to keep pace with production increases. Discussions with one operator indicate that new technologies developed over the past several years have allowed heavy oil production to occur from high gas-to-oil ratio (GOR) pools that could not previously be

50

produced. Therefore, heavy oil casing gas emissions have been scaled down to match the historical GHG emission summary. When extrapolated back to 1990, total GHG emissions are approximately 0.3 percent greater than was previously estimated, and at 1995 they are about 2.3 percent greater than was previously estimated (CAPP, 1999). The differences are attributed to the use of refined emission factors, more detailed quantification of activity data, better accounting for casing gas venting from heavy oil operations, and revised methodology for combustion sources (to be consistent with UNFCCC requirements). GHG emissions (and uncertainties) are summarized in the UNFCCC common reporting format (CRF) in Tables 11.2 and 11.3 for oil systems and gas systems, respectively. Since it is not possible to explicitly allocate exploration emissions to oil and gas systems, all emissions from well drilling and well testing have been arbitrarily allocated to the oil exploration category of the CRF forms.

1990

Table 11.1. Historical summary of GHG emissions (t/y) from upstream oil and gas operations in Canada, presented by year, province and sector.

Yukon Territory

C1 CO2 N2O CO2E CO2O NMVOCSector Source

0 0 0.0 0 0 0Natural Gas Production Flaring0 0 0.0 0 0 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Production Unreported Venting0 0 0.0 0 0 0Natural Gas Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fuel Combustion0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Processing Formation CO20 0 0.0 0 0 0Natural Gas Processing Sector Total0 0 0.0 0 0 0Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Flaring0 0 0.0 0 0 0Annual Total Fugitive Equipment Leaks0 0 0.0 0 0 0Annual Total Formation CO20 0 0.0 0 0 0Annual Total Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Annual Total Unreported Venting0 0 0.0 0 0 0Annual Total Sector Total


0 2 523 0.2 2 601 0 3Oil and Gas Well Drilling Fuel Combustion0 2 523 0.2 2 601 0 3Oil and Gas Well Drilling Sector Total0 273 0.0 283 0 0Oil and Gas Well Servicing Fuel Combustion0 273 0.0 283 0 0Oil and Gas Well Servicing Sector Total0 0 0.0 1 0 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 1 0 0Natural Gas Production Sector Total

12 226 060 5.8 228 101 0 7Conventional Oil Production Fuel Combustion36 59 931 0.0 60 689 0 30Conventional Oil Production Flaring41 8 0.0 862 216 35Conventional Oil Production Fugitive Equipment Leaks24 6 0.0 504 122 19Conventional Oil Production Glycol Dehydrator Off-Gas44 9 0.0 932 212 31Conventional Oil Production Unreported Venting

156 286 013 5.8 291 089 550 121Conventional Oil Production Sector Total2 0 0.0 45 10 1Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration1 0 0.0 14 99 32Accidents and Equipment Failures Spills/Pipeline Ruptures3 0 0.0 58 110 33Accidents and Equipment Failures Sector Total

12 228 856 6.0 230 985 0 10Annual Total Fuel Combustion

Northwest Territories

51

1990




36 59 931 0.0 60 689 0 30Annual Total Flaring41 8 0.0 863 216 35Annual Total Fugitive Equipment Leaks2 0 0.0 45 10 1Annual Total Surface Casing Vent Flow/Gas Migration1 0 0.0 14 99 32Annual Total Spills/Pipeline Ruptures

44 9 0.0 932 212 31Annual Total Unreported Venting160 288 810 6.0 294 032 660 158Annual Total Sector Total


10 78 600 7.2 81 019 0 94Oil and Gas Well Drilling Fuel Combustion24 2 0.0 508 84 6Oil and Gas Well Drilling Reported Venting34 78 602 7.2 81 528 84 100Oil and Gas Well Drilling Sector Total62 3 638 0.5 5 079 0 16Oil and Gas Well Servicing Fuel Combustion62 3 638 0.5 5 079 0 16Oil and Gas Well Servicing Sector Total43 67 530 0.0 68 430 0 35Well Testing Flaring43 67 530 0.0 68 430 0 35Well Testing Sector Total

1 340 608 605 59.0 655 042 0 540Natural Gas Production Fuel Combustion20 29 753 0.0 30 164 0 16Natural Gas Production Flaring

2 233 397 0.0 47 288 10 050 1 317Natural Gas Production Glycol Dehydrator Off-Gas7 435 244 0.0 156 371 24 482 1 381Natural Gas Production Fugitive Equipment Leaks

97 2 0.0 2 047 313 15Natural Gas Production Reported Venting4 836 112 0.0 101 672 15 493 754Natural Gas Production Unreported Venting

15 961 639 113 59.0 992 585 50 337 4 024Natural Gas Production Sector Total258 144 773 15.5 154 975 0 142Conventional Oil Production Fuel Combustion75 122 574 0.0 124 145 0 61Conventional Oil Production Flaring

6 770 1 081 0.0 143 252 34 876 5 436Conventional Oil Production Fugitive Equipment Leaks274 61 0.0 5 815 1 337 196Conventional Oil Production Glycol Dehydrator Off-Gas11 1 0.0 241 1 837 589Conventional Oil Production Loading/Unloading

571 112 0.0 12 100 2 755 399Conventional Oil Production Reported Venting196 18 0.0 4 138 14 592 4 664Conventional Oil Production Storage Losses

6 111 101 0.0 128 438 19 598 960Conventional Oil Production Unreported Venting14 266 268 721 15.5 573 103 74 995 12 449Conventional Oil Production Sector Total

635 667 807 29.9 690 418 0 260Natural Gas Processing Fuel Combustion25 39 097 0.0 39 620 0 20Natural Gas Processing Flaring27 6 0.0 574 133 20Natural Gas Processing Glycol Dehydrator Off-Gas

894 54 0.0 18 820 3 502 353Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 1 481 160Natural Gas Processing Loading/Unloading0 1 135 942 0.0 1 135 942 0 0Natural Gas Processing Formation CO2

British Columbia

52

1990


British Columbia


6 0 0.0 118 48 11Natural Gas Processing Storage Losses437 64 0.0 9 243 1 391 65Natural Gas Processing Unreported Venting

2 024 1 842 971 29.9 1 894 736 5 555 889Natural Gas Processing Sector Total0 236 0.0 239 0 0Liquid Product Transportation Flaring0 0 0.0 1 4 1Liquid Product Transportation Fugitive Equipment Leaks

14 0 0.0 293 354 105Liquid Product Transportation Storage Losses14 237 0.0 533 358 107Liquid Product Transportation Sector Total

1 257 247 0.0 26 648 12 133 879Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration95 9 0.0 2 002 14 723 4 720Accidents and Equipment Failures Spills/Pipeline Ruptures

1 352 256 0.0 28 649 26 857 5 599Accidents and Equipment Failures Sector Total2 304 1 503 422 112.0 1 586 534 0 1 052Annual Total Fuel Combustion2 534 465 0.0 53 677 11 520 1 533Annual Total Glycol Dehydrator Off-Gas

162 259 190 0.0 262 598 0 133Annual Total Flaring15 098 1 379 0.0 318 443 62 864 7 171Annual Total Fugitive Equipment Leaks

11 1 0.0 242 2 319 750Annual Total Loading/Unloading0 1 135 942 0.0 1 135 942 0 0Annual Total Formation CO2

668 114 0.0 14 147 3 067 415Annual Total Reported Venting1 257 247 0.0 26 648 12 133 879Annual Total Surface Casing Vent Flow/Gas Migration

95 9 0.0 2 002 14 723 4 720Annual Total Spills/Pipeline Ruptures216 19 0.0 4 549 14 994 4 780Annual Total Storage Losses

11 385 278 0.0 239 352 36 481 1 780Annual Total Unreported Venting24 2 0.0 508 84 6Annual Total Reported Venting

33 755 2 901 066 112.0 3 644 643 158 186 23 218Annual Total Sector Total


32 263 730 24.0 271 833 0 314Oil and Gas Well Drilling Fuel Combustion50 1 0.0 1 047 182 15Oil and Gas Well Drilling Reported Venting82 263 731 24.0 272 880 182 329Oil and Gas Well Drilling Sector Total

2 753 64 208 8.1 124 531 0 539Oil and Gas Well Servicing Fuel Combustion2 753 64 208 8.1 124 531 0 539Oil and Gas Well Servicing Sector Total

135 207 125 0.0 209 957 0 110Well Testing Flaring1 335 23 0.0 28 050 4 283 211Well Testing Reported Venting1 469 207 148 0.0 238 008 4 283 321Well Testing Sector Total8 963 4 320 724 415.9 4 637 877 0 3 940Natural Gas Production Fuel Combustion

132 199 849 0.0 202 620 0 108Natural Gas Production Flaring21 954 3 432 0.0 464 455 94 835 11 614Natural Gas Production Glycol Dehydrator Off-Gas

149 088 4 616 0.0 3 135 461 509 751 33 919Natural Gas Production Fugitive Equipment Leaks

Alberta

53

1990


Alberta


4 821 195 0.0 101 446 16 402 1 069Natural Gas Production Reported Venting4 160 272 0.0 87 633 34 283 7 639Natural Gas Production Storage Losses

101 508 1 829 0.0 2 133 504 326 524 16 282Natural Gas Production Unreported Venting290 626 4 530 917 415.9 10 762 996 981 795 74 571Natural Gas Production Sector Total

1 401 808 046 81.2 862 637 0 702Conventional Oil Production Fuel Combustion901 1 476 298 0.0 1 495 212 0 737Conventional Oil Production Flaring

74 147 8 529 0.0 1 565 623 387 719 61 247Conventional Oil Production Fugitive Equipment Leaks2 469 558 0.0 52 408 12 100 1 786Conventional Oil Production Glycol Dehydrator Off-Gas

66 8 0.0 1 393 11 378 3 656Conventional Oil Production Loading/Unloading55 609 7 009 0.0 1 174 791 246 747 31 622Conventional Oil Production Reported Venting

4 890 443 0.0 103 129 365 430 116 822Conventional Oil Production Storage Losses104 645 1 841 0.0 2 199 378 336 845 16 864Conventional Oil Production Unreported Venting244 127 2 302 731 81.2 7 454 571 1 360 220 233 436Conventional Oil Production Sector Total

704 496 247 47.3 525 695 0 396Heavy Oil/Cold Bitumen Production Fuel Combustion449 725 470 0.0 734 898 0 368Heavy Oil/Cold Bitumen Production Flaring

39 664 7 781 0.0 840 729 140 518 10 451Heavy Oil/Cold Bitumen Production Fugitive Equipment Leaks115 24 0.0 2 434 549 79Heavy Oil/Cold Bitumen Production Glycol Dehydrator Off-Gas84 63 0.0 1 823 3 434 1 046Heavy Oil/Cold Bitumen Production Loading/Unloading

116 495 92 235 0.0 2 538 637 422 759 34 090Heavy Oil/Cold Bitumen Production Reported Venting13 631 2 168 0.0 288 419 99 565 20 386Heavy Oil/Cold Bitumen Production Storage Losses54 384 966 0.0 1 143 040 174 606 8 612Heavy Oil/Cold Bitumen Production Unreported Venting

225 527 1 324 954 47.3 6 075 677 841 433 75 427Heavy Oil/Cold Bitumen Production Sector Total99 3 243 207 50.1 3 260 823 0 219Thermal Operations Fuel Combustion

180 304 520 0.0 308 303 0 147Thermal Operations Flaring161 90 0.0 3 459 1 284 276Thermal Operations Fugitive Equipment Leaks

0 0 0.0 1 8 2Thermal Operations Loading/Unloading11 530 1 339 0.0 243 464 43 366 3 899Thermal Operations Reported Venting

32 24 0.0 693 155 22Thermal Operations Storage Losses35 8 0.0 738 111 5Thermal Operations Unreported Venting

12 036 3 549 189 50.1 3 817 480 44 923 4 571Thermal Operations Sector Total10 558 6 218 003 360.8 6 551 565 0 3 307Natural Gas Processing Fuel Combustion

310 474 798 0.0 481 304 0 254Natural Gas Processing Flaring171 26 0.0 3 620 734 89Natural Gas Processing Glycol Dehydrator Off-Gas

22 043 914 0.0 463 827 92 217 10 620Natural Gas Processing Fugitive Equipment Leaks2 0 0.0 39 9 156 3 042Natural Gas Processing Loading/Unloading0 3 021 995 0.0 3 021 995 0 0Natural Gas Processing Formation CO2

187 12 0.0 3 948 1 607 365Natural Gas Processing Storage Losses3 344 246 0.0 70 468 12 368 1 073Natural Gas Processing Unreported Venting

36 616 9 715 995 360.8 10 596 766 116 082 18 749Natural Gas Processing Sector Total5 9 727 0.0 9 839 0 4Liquid Product Transportation Flaring1 0 0.0 29 167 53Liquid Product Transportation Fugitive Equipment Leaks9 0 0.0 186 28 1Liquid Product Transportation Reported Venting

773 37 0.0 16 269 28 592 8 802Liquid Product Transportation Storage Losses

54

1990


Alberta


789 9 764 0.0 26 324 28 787 8 862Liquid Product Transportation Sector Total43 319 8 506 0.0 918 212 209 044 30 303Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration

4 303 845 0.0 91 198 21 162 3 140Accidents and Equipment Failures Spills/Pipeline Ruptures47 622 9 350 0.0 1 009 410 230 206 33 444Accidents and Equipment Failures Sector Total24 510 15 414 165 987.4 16 234 961 0 9 416Annual Total Fuel Combustion24 708 4 040 0.0 522 917 108 218 13 567Annual Total Glycol Dehydrator Off-Gas2 112 3 397 787 0.0 3 442 134 0 1 729Annual Total Flaring

285 105 21 930 0.0 6 009 128 1 131 656 116 567Annual Total Fugitive Equipment Leaks152 71 0.0 3 256 23 976 7 746Annual Total Loading/Unloading

0 3 021 995 0.0 3 021 995 0 0Annual Total Formation CO2188 455 100 777 0.0 4 058 338 729 275 70 680Annual Total Reported Venting

43 319 8 506 0.0 918 212 209 044 30 303Annual Total Surface Casing Vent Flow/Gas Migration4 303 845 0.0 91 198 21 162 3 140Annual Total Spills/Pipeline Ruptures

23 673 2 956 0.0 500 091 529 632 154 036Annual Total Storage Losses263 916 4 891 0.0 5 547 128 850 455 42 836Annual Total Unreported Venting

1 393 24 0.0 29 283 4 493 227Annual Total Reported Venting861 647 21 977 987 987.4 40 378 642 3 607 910 450 248Annual Total Sector Total


5 43 194 3.7 44 435 0 48Oil and Gas Well Drilling Fuel Combustion29 0 0.0 601 92 5Oil and Gas Well Drilling Reported Venting34 43 194 3.7 45 036 92 52Oil and Gas Well Drilling Sector Total

480 29 817 3.4 40 961 0 120Oil and Gas Well Servicing Fuel Combustion480 29 817 3.4 40 961 0 120Oil and Gas Well Servicing Sector Total291 190 035 17.5 201 575 0 163Natural Gas Production Fuel Combustion

2 2 638 0.0 2 675 0 1Natural Gas Production Flaring1 449 84 0.0 30 508 5 071 369Natural Gas Production Glycol Dehydrator Off-Gas

18 718 407 0.0 393 492 62 139 3 642Natural Gas Production Fugitive Equipment Leaks11 209 189 0.0 235 585 35 959 1 765Natural Gas Production Unreported Venting31 669 193 354 17.5 863 834 103 168 5 941Natural Gas Production Sector Total

150 153 124 13.6 160 492 0 85Conventional Oil Production Fuel Combustion163 265 359 0.0 268 791 0 134Conventional Oil Production Flaring

11 645 2 014 0.0 246 555 96 345 21 227Conventional Oil Production Fugitive Equipment Leaks44 4 0.0 924 6 796 2 178Conventional Oil Production Loading/Unloading


10 978 187 0.0 230 732 35 222 1 730Conventional Oil Production Unreported Venting

Saskatchewan

55

1990


Saskatchewan


24 246 420 861 13.6 934 249 194 277 42 764Conventional Oil Production Sector Total49 329 474 11.0 333 895 0 43Heavy Oil/Cold Bitumen Production Fuel Combustion21 31 035 0.0 31 467 0 17Heavy Oil/Cold Bitumen Production Flaring

10 131 60 0.0 212 811 43 049 4 985Heavy Oil/Cold Bitumen Production Fugitive Equipment Leaks6 1 0.0 119 29 5Heavy Oil/Cold Bitumen Production Glycol Dehydrator Off-Gas4 1 0.0 79 761 245Heavy Oil/Cold Bitumen Production Loading/Unloading

82 167 257 0.0 1 725 760 243 799 6 117Heavy Oil/Cold Bitumen Production Reported Venting2 368 141 0.0 49 877 16 598 3 300Heavy Oil/Cold Bitumen Production Storage Losses

18 910 328 0.0 397 446 60 687 2 986Heavy Oil/Cold Bitumen Production Unreported Venting113 655 361 298 11.0 2 751 455 364 923 17 698Heavy Oil/Cold Bitumen Production Sector Total

18 224 166 4.8 226 019 0 23Thermal Operations Fuel Combustion6 8 497 0.0 8 615 0 5Thermal Operations Flaring

75 1 0.0 1 572 311 35Thermal Operations Fugitive Equipment Leaks1 0 0.0 11 107 34Thermal Operations Loading/Unloading

5 830 2 0.0 122 424 18 453 833Thermal Operations Reported Venting404 29 0.0 8 505 2 804 554Thermal Operations Storage Losses

9 0 0.0 182 28 1Thermal Operations Unreported Venting6 341 232 696 4.8 367 329 21 703 1 485Thermal Operations Sector Total


549 13 0.0 11 540 2 125 207Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 205 69Natural Gas Processing Loading/Unloading0 8 036 0.0 8 036 0 0Natural Gas Processing Formation CO22 0 0.0 51 21 5Natural Gas Processing Storage Losses

613 54 482 2.7 68 188 2 356 319Natural Gas Processing Sector Total0 53 0.0 53 0 0Liquid Product Transportation Flaring0 0 0.0 6 43 14Liquid Product Transportation Fugitive Equipment Leaks

183 6 0.0 3 839 4 640 1 379Liquid Product Transportation Storage Losses183 59 0.0 3 898 4 683 1 393Liquid Product Transportation Sector Total

22 033 4 326 0.0 467 009 106 321 15 412Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration19 2 0.0 409 3 010 965Accidents and Equipment Failures Spills/Pipeline Ruptures

22 052 4 328 0.0 467 418 109 331 16 377Accidents and Equipment Failures Sector Total1 039 995 277 56.7 1 034 659 0 508Annual Total Fuel Combustion1 455 86 0.0 30 650 5 104 374Annual Total Glycol Dehydrator Off-Gas


48 5 0.0 1 014 7 869 2 526Annual Total Loading/Unloading0 8 036 0.0 8 036 0 0Annual Total Formation CO2

88 547 367 0.0 1 859 854 264 909 7 335Annual Total Reported Venting22 033 4 326 0.0 467 009 106 321 15 412Annual Total Surface Casing Vent Flow/Gas Migration

19 2 0.0 409 3 010 965Annual Total Spills/Pipeline Ruptures3 672 241 0.0 77 357 77 320 22 262Annual Total Storage Losses

56

1990


Saskatchewan





1 11 193 0.9 11 509 0 0Oil and Gas Well Drilling Fuel Combustion1 11 193 0.9 11 509 0 0Oil and Gas Well Drilling Sector Total0 1 721 0.2 1 786 0 15Oil and Gas Well Servicing Fuel Combustion0 1 721 0.2 1 786 0 15Oil and Gas Well Servicing Sector Total5 13 746 0.9 14 125 0 3Conventional Oil Production Fuel Combustion

17 28 249 0.0 28 609 0 14Conventional Oil Production Flaring156 143 0.0 3 410 5 108 1 547Conventional Oil Production Fugitive Equipment Leaks129 121 0.0 2 821 3 884 1 183Conventional Oil Production Reported Venting

67 6 0.0 1 420 5 056 1 617Conventional Oil Production Storage Losses839 15 0.0 17 624 2 691 132Conventional Oil Production Unreported Venting

1 212 42 279 0.9 68 010 16 740 4 496Conventional Oil Production Sector Total0 0 0.0 1 6 2Liquid Product Transportation Fugitive Equipment Leaks


1 489 292 0.0 31 571 7 187 1 042Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration0 0 0.0 10 75 24Accidents and Equipment Failures Spills/Pipeline Ruptures

1 490 292 0.0 31 581 7 262 1 066Accidents and Equipment Failures Sector Total7 26 659 2.0 27 420 0 18Annual Total Fuel Combustion

17 28 249 0.0 28 609 0 14Annual Total Flaring156 143 0.0 3 411 5 115 1 549Annual Total Fugitive Equipment Leaks129 121 0.0 2 821 3 884 1 183Annual Total Reported Venting

1 489 292 0.0 31 571 7 187 1 042Annual Total Surface Casing Vent Flow/Gas Migration0 0 0.0 10 75 24Annual Total Spills/Pipeline Ruptures

90 7 0.0 1 887 5 622 1 785Annual Total Storage Losses839 15 0.0 17 624 2 691 132Annual Total Unreported Venting

2 726 55 485 2.0 113 353 24 573 5 747Annual Total Sector Total

Manitoba

57

1990


Ontario


1 7 606 0.7 7 830 0 9Oil and Gas Well Drilling Fuel Combustion1 7 606 0.7 7 830 0 9Oil and Gas Well Drilling Sector Total0 867 0.1 899 0 1Oil and Gas Well Servicing Fuel Combustion0 867 0.1 899 0 1Oil and Gas Well Servicing Sector Total1 872 0.1 918 0 1Natural Gas Production Fuel Combustion

353 6 0.0 7 419 1 161 65Natural Gas Production Fugitive Equipment Leaks135 1 0.0 2 826 430 21Natural Gas Production Unreported Venting489 878 0.1 11 163 1 591 87Natural Gas Production Sector Total

0 1 649 0.1 1 686 0 0Conventional Oil Production Fuel Combustion856 72 0.0 18 058 4 893 842Conventional Oil Production Fugitive Equipment Leaks942 16 0.0 19 801 3 023 149Conventional Oil Production Unreported Venting

1 799 1 737 0.1 39 545 7 917 991Conventional Oil Production Sector Total0 1 151 0.0 1 158 0 0Natural Gas Processing Fuel Combustion

34 1 0.0 708 129 12Natural Gas Processing Fugitive Equipment Leaks47 0 0.0 993 150 7Natural Gas Processing Unreported Venting81 1 152 0.0 2 858 279 19Natural Gas Processing Sector Total

0 35 0.0 36 0 0Liquid Product Transportation Flaring0 0 0.0 2 15 5Liquid Product Transportation Fugitive Equipment Leaks

58 2 0.0 1 210 1 462 435Liquid Product Transportation Storage Losses58 37 0.0 1 247 1 477 439Liquid Product Transportation Sector Total

1 451 285 0.0 30 757 7 002 1 015Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration1 451 285 0.0 30 757 7 002 1 015Accidents and Equipment Failures Sector Total

2 12 144 1.0 12 492 0 11Annual Total Fuel Combustion0 35 0.0 36 0 0Annual Total Flaring

1 243 78 0.0 26 186 6 198 924Annual Total Fugitive Equipment Leaks1 451 285 0.0 30 757 7 002 1 015Annual Total Surface Casing Vent Flow/Gas Migration

58 2 0.0 1 210 1 462 435Annual Total Storage Losses1 124 18 0.0 23 620 3 604 176Annual Total Unreported Venting3 878 12 562 1.0 94 300 18 266 2 561Annual Total Sector Total


0 0 0.0 0 0 0Oil and Gas Well Drilling Fuel Combustion0 0 0.0 0 0 0Oil and Gas Well Drilling Sector Total0 0 0.0 0 0 0Oil and Gas Well Servicing Fuel Combustion0 0 0.0 0 0 0Oil and Gas Well Servicing Sector Total

Nova Scotia

58

1990


Nova Scotia


0 0 0.0 0 0 0Natural Gas Production Fuel Combustion0 0 0.0 0 0 0Natural Gas Production Flaring0 0 0.0 0 0 0Natural Gas Production Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Production Unreported Venting0 0 0.0 0 0 0Natural Gas Production Sector Total0 0 0.0 0 0 0Conventional Oil Production Fugitive Equipment Leaks0 0 0.0 0 0 0Conventional Oil Production Storage Losses0 0 0.0 0 0 0Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fuel Combustion0 0 0.0 0 0 0Natural Gas Processing Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Processing Sector Total0 0 0.0 0 0 0Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Annual Total Flaring0 0 0.0 0 0 0Annual Total Fugitive Equipment Leaks0 0 0.0 0 0 0Annual Total Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting0 0 0.0 0 0 0Annual Total Sector Total


0 0 0.0 0 0 0Oil and Gas Well Drilling Fuel Combustion0 0 0.0 0 0 0Oil and Gas Well Drilling Sector Total0 0 0.0 0 0 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Production Sector Total0 0 0.0 0 0 0Conventional Oil Production Fuel Combustion0 0 0.0 0 0 0Conventional Oil Production Flaring0 0 0.0 0 0 0Conventional Oil Production Fugitive Equipment Leaks0 0 0.0 0 0 0Conventional Oil Production Loading/Unloading0 0 0.0 0 0 0Conventional Oil Production Storage Losses0 0 0.0 0 0 0Conventional Oil Production Unreported Venting0 0 0.0 0 0 0Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks

Newfoundland

59

1990


Newfoundland


0 0 0.0 0 0 0Natural Gas Processing Sector Total0 0 0.0 0 0 0Accidents and Equipment Failures Spills/Pipeline Ruptures0 0 0.0 0 0 0Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Flaring0 0 0.0 0 0 0Annual Total Fugitive Equipment Leaks0 0 0.0 0 0 0Annual Total Loading/Unloading0 0 0.0 0 0 0Annual Total Spills/Pipeline Ruptures0 0 0.0 0 0 0Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting0 0 0.0 0 0 0Annual Total Sector Total




178 274 655 0.0 278 388 0 146Well Testing Flaring1 335 23 0.0 28 050 4 283 211Well Testing Reported Venting1 512 274 678 0.0 306 438 4 283 356Well Testing Sector Total

10 595 5 120 236 492.5 5 495 413 0 4 644Natural Gas Production Fuel Combustion153 232 240 0.0 235 460 0 126Natural Gas Production Flaring

25 635 3 913 0.0 542 251 109 955 13 299Natural Gas Production Glycol Dehydrator Off-Gas175 594 5 273 0.0 3 692 744 597 533 39 007Natural Gas Production Fugitive Equipment Leaks


117 688 2 132 0.0 2 473 587 378 405 18 822Natural Gas Production Unreported Venting338 744 5 364 262 492.5 12 630 579 1 136 892 84 621Natural Gas Production Sector Total

1 826 1 347 396 117.0 1 422 016 0 938Conventional Oil Production Fuel Combustion1 192 1 952 410 0.0 1 977 445 0 976Conventional Oil Production Flaring



5 869 531 0.0 123 772 438 336 140 127Conventional Oil Production Storage Losses123 559 2 169 0.0 2 596 904 397 592 19 866Conventional Oil Production Unreported Venting

Canada

60

1990


Canada


285 807 3 322 341 117.0 9 360 566 1 654 699 294 257Conventional Oil Production Sector Total753 825 722 58.3 859 591 0 438Heavy Oil/Cold Bitumen Production Fuel Combustion470 756 505 0.0 766 365 0 384Heavy Oil/Cold Bitumen Production Flaring

49 795 7 840 0.0 1 053 540 183 567 15 436Heavy Oil/Cold Bitumen Production Fugitive Equipment Leaks120 26 0.0 2 553 578 83Heavy Oil/Cold Bitumen Production Glycol Dehydrator Off-Gas88 64 0.0 1 902 4 195 1 291Heavy Oil/Cold Bitumen Production Loading/Unloading

198 662 92 492 0.0 4 264 398 666 558 40 207Heavy Oil/Cold Bitumen Production Reported Venting15 999 2 309 0.0 338 296 116 163 23 686Heavy Oil/Cold Bitumen Production Storage Losses73 295 1 294 0.0 1 540 486 235 294 11 598Heavy Oil/Cold Bitumen Production Unreported Venting

339 182 1 686 252 58.3 8 827 131 1 206 356 93 124Heavy Oil/Cold Bitumen Production Sector Total117 3 467 373 54.9 3 486 842 0 242Thermal Operations Fuel Combustion186 313 017 0.0 316 918 0 152Thermal Operations Flaring236 91 0.0 5 031 1 594 311Thermal Operations Fugitive Equipment Leaks


435 53 0.0 9 198 2 959 576Thermal Operations Storage Losses43 9 0.0 920 139 7Thermal Operations Unreported Venting






1 049 46 0.0 22 079 35 613 10 890Liquid Product Transportation Storage Losses1 065 10 098 0.0 32 470 35 877 10 971Liquid Product Transportation Sector Total

69 552 13 656 0.0 1 474 240 341 698 48 654Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration4 418 855 0.0 93 632 39 069 8 880Accidents and Equipment Failures Spills/Pipeline Ruptures

73 970 14 511 0.0 1 567 873 380 767 57 534Accidents and Equipment Failures Sector Total27 875 18 180 524 1 165.0 19 127 051 0 11 014Annual Total Fuel Combustion28 722 4 596 0.0 607 749 124 964 15 493Annual Total Glycol Dehydrator Off-Gas2 533 4 073 739 0.0 4 126 923 0 2 073Annual Total Flaring


0 4 165 973 0.0 4 165 973 0 0Annual Total Formation CO2277 799 101 378 0.0 5 935 161 1 001 135 79 612Annual Total Reported Venting

69 552 13 656 0.0 1 474 240 341 698 48 654Annual Total Surface Casing Vent Flow/Gas Migration

61

1990


Canada


4 418 855 0.0 93 632 39 069 8 880Annual Total Spills/Pipeline Ruptures27 708 3 224 0.0 585 095 629 030 183 299Annual Total Storage Losses

318 414 5 914 0.0 6 692 601 1 025 339 51 438Annual Total Unreported Venting1 446 27 0.0 30 393 4 669 238Annual Total Reported Venting

1 101 437 26 575 998 1 165.0 50 067 337 4 610 129 568 080Annual Total Sector Total

62

1991


Yukon Territory


1 1 461 0.0 1 481 0 1Natural Gas Production Flaring12 0 0.0 261 42 3Natural Gas Production Fugitive Equipment Leaks

8 0 0.0 177 27 1Natural Gas Production Unreported Venting22 1 462 0.0 1 919 68 5Natural Gas Production Sector Total18 11 222 1.1 11 934 0 10Natural Gas Processing Fuel Combustion5 1 0.0 102 16 1Natural Gas Processing Fugitive Equipment Leaks0 853 0.0 853 0 0Natural Gas Processing Formation CO2

23 12 076 1.1 12 888 16 11Natural Gas Processing Sector Total4 1 0.0 83 19 3Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration4 1 0.0 83 19 3Accidents and Equipment Failures Sector Total

18 11 222 1.1 11 934 0 10Annual Total Fuel Combustion1 1 461 0.0 1 481 0 1Annual Total Flaring

17 1 0.0 363 57 3Annual Total Fugitive Equipment Leaks0 853 0.0 853 0 0Annual Total Formation CO24 1 0.0 83 19 3Annual Total Surface Casing Vent Flow/Gas Migration8 0 0.0 177 27 1Annual Total Unreported Venting

49 13 538 1.1 14 891 103 18Annual Total Sector Total







63

1991




25 6 0.0 521 126 20Annual Total Glycol Dehydrator Off-Gas39 64 229 0.0 65 042 0 32Annual Total Flaring41 8 0.0 863 216 35Annual Total Fugitive Equipment Leaks2 0 0.0 48 11 2Annual Total Surface Casing Vent Flow/Gas Migration1 0 0.0 14 99 32Annual Total Spills/Pipeline Ruptures




806 366 135 35.5 394 071 0 325Natural Gas Production Fuel Combustion4 6 248 0.0 6 334 0 3Natural Gas Production Flaring



17 683 373 255 35.5 755 600 58 168 4 335Natural Gas Production Sector Total155 87 095 9.3 93 232 0 85Conventional Oil Production Fuel Combustion

16 25 739 0.0 26 069 0 13Conventional Oil Production Flaring6 770 1 081 0.0 143 252 34 876 5 436Conventional Oil Production Fugitive Equipment Leaks

289 64 0.0 6 124 1 408 207Conventional Oil Production Glycol Dehydrator Off-Gas12 1 0.0 254 1 935 621Conventional Oil Production Loading/Unloading


6 436 106 0.0 135 259 20 639 1 011Conventional Oil Production Unreported Venting14 485 114 224 9.3 421 290 77 126 12 706Conventional Oil Production Sector Total

382 401 750 18.0 415 353 0 156Natural Gas Processing Fuel Combustion5 8 210 0.0 8 320 0 4Natural Gas Processing Flaring

31 7 0.0 663 153 23Natural Gas Processing Glycol Dehydrator Off-Gas1 033 62 0.0 21 747 4 047 407Natural Gas Processing Fugitive Equipment Leaks

0 0 0.0 2 556 185Natural Gas Processing Loading/Unloading

British Columbia

64

1991


British Columbia


0 1 312 652 0.0 1 312 652 0 0Natural Gas Processing Formation CO26 0 0.0 137 55 13Natural Gas Processing Storage Losses

505 74 0.0 10 680 1 607 75Natural Gas Processing Unreported Venting1 963 1 722 756 18.0 1 769 554 6 419 864Natural Gas Processing Sector Total



1 426 280 0.0 30 219 13 760 997Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration133 12 0.0 2 816 20 711 6 639Accidents and Equipment Failures Spills/Pipeline Ruptures

1 559 292 0.0 33 035 34 471 7 636Accidents and Equipment Failures Sector Total1 398 918 462 68.7 969 119 0 651Annual Total Fuel Combustion2 900 531 0.0 61 431 13 175 1 751Annual Total Glycol Dehydrator Off-Gas



714 120 0.0 15 109 3 262 438Annual Total Reported Venting1 426 280 0.0 30 219 13 760 997Annual Total Surface Casing Vent Flow/Gas Migration









Alberta

65

1991


Alberta


154 775 4 793 0.0 3 255 061 529 195 35 213Natural Gas Production Fugitive Equipment Leaks5 005 202 0.0 105 315 17 028 1 110Natural Gas Production Reported Venting4 319 282 0.0 90 976 35 591 7 930Natural Gas Production Storage Losses







43 902 8 612 0.0 930 560 155 532 11 568Heavy Oil/Cold Bitumen Production Fugitive Equipment Leaks127 27 0.0 2 694 608 87Heavy Oil/Cold Bitumen Production Glycol Dehydrator Off-Gas

93 70 0.0 2 018 3 801 1 157Heavy Oil/Cold Bitumen Production Loading/Unloading132 759 105 112 0.0 2 893 061 481 782 38 850Heavy Oil/Cold Bitumen Production Reported Venting

15 087 2 400 0.0 319 236 110 204 22 564Heavy Oil/Cold Bitumen Production Storage Losses60 195 1 069 0.0 1 265 172 193 263 9 532Heavy Oil/Cold Bitumen Production Unreported Venting

253 328 1 356 765 47.3 6 691 320 945 189 84 530Heavy Oil/Cold Bitumen Production Sector Total99 3 242 535 50.1 3 260 148 0 219Thermal Operations Fuel Combustion

185 312 017 0.0 315 894 0 151Thermal Operations Flaring164 92 0.0 3 524 1 308 281Thermal Operations Fugitive Equipment Leaks








66

1991


Alberta


752 36 0.0 15 835 27 827 8 567Liquid Product Transportation Storage Losses768 10 003 0.0 26 125 28 018 8 625Liquid Product Transportation Sector Total

46 930 9 215 0.0 994 750 226 469 32 829Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration1 530 300 0.0 32 425 7 524 1 116Accidents and Equipment Failures Spills/Pipeline Ruptures

48 460 9 515 0.0 1 027 175 233 993 33 946Accidents and Equipment Failures Sector Total24 063 15 358 867 982.1 16 168 620 0 9 279Annual Total Fuel Combustion25 452 4 149 0.0 538 631 111 368 13 940Annual Total Glycol Dehydrator Off-Gas2 139 3 443 389 0.0 3 488 307 0 1 751Annual Total Flaring



46 930 9 215 0.0 994 750 226 469 32 829Annual Total Surface Casing Vent Flow/Gas Migration1 530 300 0.0 32 425 7 524 1 116Annual Total Spills/Pipeline Ruptures


1 173 20 0.0 24 649 3 782 191Annual Total Reported Venting893 874 22 097 790 982.1 41 173 578 3 712 143 454 983Annual Total Sector Total









Saskatchewan

67

1991


Saskatchewan









5 950 2 0.0 124 957 18 835 850Thermal Operations Reported Venting412 30 0.0 8 681 2 862 566Thermal Operations Storage Losses







24 273 4 764 0.0 514 506 120 051 17 931Accidents and Equipment Failures Sector Total988 1 042 586 58.6 1 081 519 0 500Annual Total Fuel Combustion

1 535 91 0.0 32 329 5 383 394Annual Total Glycol Dehydrator Off-Gas220 352 708 0.0 357 334 0 180Annual Total Flaring

42 387 2 520 0.0 892 650 208 438 30 426Annual Total Fugitive Equipment Leaks49 5 0.0 1 025 7 969 2 558Annual Total Loading/Unloading0 8 477 0.0 8 477 0 0Annual Total Formation CO2


19 2 0.0 409 3 010 965Annual Total Spills/Pipeline Ruptures

68

1991


Saskatchewan


3 740 245 0.0 78 777 78 341 22 539Annual Total Storage Losses42 228 723 0.0 887 511 135 493 6 659Annual Total Unreported Venting

23 0 0.0 494 75 4Annual Total Reported Venting208 300 1 412 501 58.6 5 804 977 833 479 88 860Annual Total Sector Total













Manitoba

69

1991


Ontario















Nova Scotia

70

1991


Nova Scotia


0 0 0.0 0 0 0Natural Gas Production Fuel Combustion0 0 0.0 0 0 0Natural Gas Production Flaring0 0 0.0 0 0 0Natural Gas Production Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Production Unreported Venting0 0 0.0 0 0 0Natural Gas Production Sector Total0 0 0.0 0 0 0Conventional Oil Production Fugitive Equipment Leaks0 0 0.0 0 0 0Conventional Oil Production Storage Losses0 0 0.0 0 0 0Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fuel Combustion0 0 0.0 0 0 0Natural Gas Processing Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Processing Sector Total0 0 0.0 0 0 0Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Annual Total Flaring0 0 0.0 0 0 0Annual Total Fugitive Equipment Leaks0 0 0.0 0 0 0Annual Total Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting0 0 0.0 0 0 0Annual Total Sector Total



Newfoundland

71

1991


Newfoundland




41 335 784 30.2 346 005 0 388Oil and Gas Well Drilling Fuel Combustion84 3 0.0 1 766 293 21Oil and Gas Well Drilling Reported Venting

125 335 787 30.2 347 771 293 409Oil and Gas Well Drilling Sector Total2 757 83 612 10.3 144 687 0 576Oil and Gas Well Servicing Fuel Combustion2 757 83 612 10.3 144 687 0 576Oil and Gas Well Servicing Sector Total










Canada

72

1991


Canada







444 54 0.0 9 387 3 020 588Thermal Operations Storage Losses44 9 0.0 938 141 7Thermal Operations Unreported Venting



24 533 1 027 0.0 516 216 102 162 11 664Natural Gas Processing Fugitive Equipment Leaks2 0 0.0 42 10 278 3 416Natural Gas Processing Loading/Unloading0 4 459 249 0.0 4 459 249 0 0Natural Gas Processing Formation CO2









73

1991


Canada





74

1992


Yukon Territory


1 1 461 0.0 1 481 0 1Natural Gas Production Flaring28 1 0.0 583 93 6Natural Gas Production Fugitive Equipment Leaks19 0 0.0 394 60 3Natural Gas Production Unreported Venting47 1 462 0.0 2 458 153 9Natural Gas Production Sector Total18 11 222 1.1 11 934 0 10Natural Gas Processing Fuel Combustion11 3 0.0 227 35 2Natural Gas Processing Fugitive Equipment Leaks

0 1 903 0.0 1 903 0 0Natural Gas Processing Formation CO229 13 128 1.1 14 063 35 12Natural Gas Processing Sector Total

4 1 0.0 88 20 3Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration4 1 0.0 88 20 3Accidents and Equipment Failures Sector Total


38 3 0.0 809 128 8Annual Total Fugitive Equipment Leaks0 1 903 0.0 1 903 0 0Annual Total Formation CO24 1 0.0 88 20 3Annual Total Surface Casing Vent Flow/Gas Migration








75

1992











19 085 257 054 23.0 664 962 63 953 4 626Natural Gas Production Sector Total100 56 359 6.0 60 331 0 55Conventional Oil Production Fuel Combustion

48 78 967 0.0 79 979 0 39Conventional Oil Production Flaring6 770 1 081 0.0 143 252 34 876 5 436Conventional Oil Production Fugitive Equipment Leaks

291 65 0.0 6 179 1 421 209Conventional Oil Production Glycol Dehydrator Off-Gas12 1 0.0 256 1 952 626Conventional Oil Production Loading/Unloading




1 135 69 0.0 23 910 4 450 448Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 2 612 204Natural Gas Processing Loading/Unloading

British Columbia

76

1992


British Columbia






1 554 305 0.0 32 930 14 994 1 087Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration97 9 0.0 2 037 14 984 4 803Accidents and Equipment Failures Spills/Pipeline Ruptures


3 162 578 0.0 66 988 14 358 1 906Annual Total Glycol Dehydrator Off-Gas103 163 993 0.0 166 149 0 84Annual Total Flaring

17 351 1 459 0.0 365 832 70 434 7 640Annual Total Fugitive Equipment Leaks12 1 0.0 258 2 564 830Annual Total Loading/Unloading0 1 443 215 0.0 1 443 215 0 0Annual Total Formation CO2

730 121 0.0 15 460 3 325 444Annual Total Reported Venting1 554 305 0.0 32 930 14 994 1 087Annual Total Surface Casing Vent Flow/Gas Migration









Alberta

77

1992


Alberta



















78

1992


Alberta







50 893 9 993 0.0 1 078 740 245 590 35 601Annual Total Surface Casing Vent Flow/Gas Migration1 671 328 0.0 35 411 8 217 1 219Annual Total Spills/Pipeline Ruptures


1 307 23 0.0 27 477 4 216 213Annual Total Reported Venting978 370 23 971 380 1 078.8 44 851 578 4 012 200 480 838Annual Total Sector Total









Saskatchewan

79

1992


Saskatchewan









7 067 2 0.0 148 403 22 369 1 010Thermal Operations Reported Venting489 35 0.0 10 310 3 399 672Thermal Operations Storage Losses11 0 0.0 221 34 2Thermal Operations Unreported Venting

7 682 236 851 4.8 399 671 26 308 1 795Thermal Operations Sector Total47 25 943 2.8 27 792 0 26Natural Gas Processing Fuel Combustion14 20 867 0.0 21 156 0 11Natural Gas Processing Flaring1 0 0.0 25 5 1Natural Gas Processing Glycol Dehydrator Off-Gas





26 196 5 142 0.0 555 267 129 331 19 276Accidents and Equipment Failures Sector Total858 983 782 54.8 1 018 795 0 448Annual Total Fuel Combustion

1 568 93 0.0 33 030 5 502 404Annual Total Glycol Dehydrator Off-Gas204 327 009 0.0 331 297 0 167Annual Total Flaring

44 770 2 541 0.0 942 708 218 174 31 474Annual Total Fugitive Equipment Leaks51 6 0.0 1 067 8 319 2 671Annual Total Loading/Unloading0 8 656 0.0 8 656 0 0Annual Total Formation CO2



80

1992


Saskatchewan


4 304 280 0.0 90 655 83 820 23 832Annual Total Storage Losses46 390 795 0.0 974 979 148 848 7 316Annual Total Unreported Venting

17 0 0.0 365 56 3Annual Total Reported Venting237 496 1 328 747 54.8 6 333 145 932 203 94 855Annual Total Sector Total


0 4 018 0.3 4 131 0 0Oil and Gas Well Drilling Fuel Combustion0 4 018 0.3 4 131 0 0Oil and Gas Well Drilling Sector Total0 618 0.1 641 0 5Oil and Gas Well Servicing Fuel Combustion0 618 0.1 641 0 5Oil and Gas Well Servicing Sector Total5 12 235 0.8 12 573 0 3Conventional Oil Production Fuel Combustion











Manitoba

81

1992


Ontario















Nova Scotia

82

1992


Nova Scotia


0 0 0.0 0 0 0Natural Gas Production Fuel Combustion0 0 0.0 0 0 0Natural Gas Production Flaring0 0 0.0 0 0 0Natural Gas Production Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Production Unreported Venting0 0 0.0 0 0 0Natural Gas Production Sector Total

202 18 0.0 4 265 0 4 654Conventional Oil Production Fugitive Equipment Leaks32 3 0.0 666 0 727Conventional Oil Production Storage Losses

234 21 0.0 4 931 0 5 381Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fuel Combustion0 0 0.0 0 0 0Natural Gas Processing Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Processing Sector Total7 1 0.0 152 35 5Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration7 1 0.0 152 35 5Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Annual Total Flaring

202 18 0.0 4 265 0 4 654Annual Total Fugitive Equipment Leaks7 1 0.0 152 35 5Annual Total Surface Casing Vent Flow/Gas Migration

32 3 0.0 666 0 727Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting

241 23 0.0 5 083 35 5 386Annual Total Sector Total



Newfoundland

83

1992


Newfoundland















Canada

84

1992


Canada







525 63 0.0 11 098 3 575 697Thermal Operations Storage Losses50 10 0.0 1 060 160 8Thermal Operations Unreported Venting


347 531 845 0.0 539 128 0 284Natural Gas Processing Flaring231 38 0.0 4 899 1 014 127Natural Gas Processing Glycol Dehydrator Off-Gas










85

1992


Canada





86

1993


Yukon Territory














87

1993










133 2 0.0 2 802 428 21Natural Gas Production Reported Venting6 618 154 0.0 139 137 21 201 1 032Natural Gas Production Unreported Venting

20 393 198 058 17.7 631 800 68 886 4 915Natural Gas Production Sector Total77 43 433 4.6 46 494 0 43Conventional Oil Production Fuel Combustion36 59 475 0.0 60 237 0 30Conventional Oil Production Flaring






British Columbia

88

1993


British Columbia








3 381 617 0.0 71 615 15 342 2 035Annual Total Glycol Dehydrator Off-Gas109 173 085 0.0 175 370 0 89Annual Total Flaring

18 167 1 488 0.0 382 998 73 176 7 810Annual Total Fugitive Equipment Leaks12 1 0.0 255 2 591 839Annual Total Loading/Unloading0 1 554 523 0.0 1 554 523 0 0Annual Total Formation CO2










27 307 4 268 0.0 577 721 117 962 14 446Natural Gas Production Glycol Dehydrator Off-Gas

Alberta

89

1993


Alberta




1 690 974 637 98.0 1 040 483 0 846Conventional Oil Production Fuel Combustion937 1 536 373 0.0 1 556 056 0 767Conventional Oil Production Flaring















90

1993


Alberta









2 222 39 0.0 46 709 7 168 363Annual Total Reported Venting1 019 110 26 314 525 1 203.5 48 088 906 4 167 783 501 129Annual Total Sector Total





20 682 450 0.0 434 767 68 657 4 024Natural Gas Production Fugitive Equipment Leaks12 385 209 0.0 260 296 39 731 1 950Natural Gas Production Unreported Venting35 073 267 871 24.3 1 011 957 113 990 6 610Natural Gas Production Sector Total


11 645 2 014 0.0 246 555 96 345 21 227Conventional Oil Production Fugitive Equipment Leaks50 5 0.0 1 059 7 793 2 498Conventional Oil Production Loading/Unloading


Saskatchewan

91

1993


Saskatchewan


12 590 214 0.0 264 602 40 392 1 984Conventional Oil Production Unreported Venting26 146 542 547 18.9 1 097 481 208 653 45 957Conventional Oil Production Sector Total


14 079 83 0.0 295 735 59 824 6 928Heavy Oil/Cold Bitumen Production Fugitive Equipment Leaks8 2 0.0 166 40 6Heavy Oil/Cold Bitumen Production Glycol Dehydrator Off-Gas5 1 0.0 110 1 058 340Heavy Oil/Cold Bitumen Production Loading/Unloading











29 832 5 855 0.0 632 330 146 875 21 820Accidents and Equipment Failures Sector Total1 568 1 400 870 80.5 1 458 763 0 748Annual Total Fuel Combustion1 610 95 0.0 33 899 5 648 415Annual Total Glycol Dehydrator Off-Gas





92

1993


Saskatchewan


4 898 318 0.0 103 178 93 730 26 570Annual Total Storage Losses51 266 879 0.0 1 077 467 164 496 8 086Annual Total Unreported Venting

47 1 0.0 991 151 7Annual Total Reported Venting269 703 1 825 474 80.5 7 514 201 1 045 360 104 144Annual Total Sector Total













Manitoba

93

1993


Ontario















Nova Scotia

94

1993


Nova Scotia



202 18 0.0 4 265 0 4 654Conventional Oil Production Fugitive Equipment Leaks57 5 0.0 1 204 0 1 314Conventional Oil Production Storage Losses



57 5 0.0 1 204 0 1 314Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting




Newfoundland

95

1993


Newfoundland





5 266 159 159 19.5 275 788 0 1 097Oil and Gas Well Servicing Fuel Combustion5 266 159 159 19.5 275 788 0 1 097Oil and Gas Well Servicing Sector Total






1 991 1 467 873 128.1 1 549 393 0 1 016Conventional Oil Production Fuel Combustion1 225 2 005 840 0.0 2 031 567 0 1 003Conventional Oil Production Flaring




Canada

96

1993


Canada


285 397 3 496 147 128.1 9 529 191 1 652 660 300 432Conventional Oil Production Sector Total917 1 056 030 72.3 1 097 688 0 537Heavy Oil/Cold Bitumen Production Fuel Combustion493 793 295 0.0 803 639 0 403Heavy Oil/Cold Bitumen Production Flaring

















97

1993


Canada





98

1994


Yukon Territory














99

1994








113 6 702 0.9 9 356 0 29Oil and Gas Well Servicing Fuel Combustion113 6 702 0.9 9 356 0 29Oil and Gas Well Servicing Sector Total79 124 397 0.0 126 056 0 65Well Testing Flaring79 124 397 0.0 126 056 0 65Well Testing Sector Total




23 313 642 242 57.3 1 149 578 75 769 5 771Natural Gas Production Sector Total250 140 622 15.0 150 531 0 138Conventional Oil Production Fuel Combustion126 205 789 0.0 208 427 0 103Conventional Oil Production Flaring






British Columbia

100

1994


British Columbia



658 97 0.0 13 912 2 094 98Natural Gas Processing Unreported Venting2 711 2 424 342 29.0 2 490 279 8 362 1 203Natural Gas Processing Sector Total

















Alberta

101

1994


Alberta




1 810 1 044 201 104.9 1 114 747 0 907Conventional Oil Production Fuel Combustion897 1 470 448 0.0 1 489 287 0 734Conventional Oil Production Flaring















102

1994


Alberta








28 486 3 589 0.0 601 796 564 773 161 273Annual Total Storage Losses311 245 5 803 0.0 6 541 944 1 003 144 50 576Annual Total Unreported Venting










Saskatchewan

103

1994


Saskatchewan
















239 382 562 0.0 387 579 0 196Annual Total Flaring51 034 2 624 0.0 1 074 331 242 148 33 712Annual Total Fugitive Equipment Leaks




104

1994


Saskatchewan


5 493 358 0.0 115 700 107 937 30 736Annual Total Storage Losses57 663 989 0.0 1 211 920 185 023 9 094Annual Total Unreported Venting

50 1 0.0 1 046 160 8Annual Total Reported Venting302 816 1 961 437 89.2 8 348 236 1 168 654 115 122Annual Total Sector Total













Manitoba

105

1994


Ontario




0 1 574 0.1 1 610 0 0Conventional Oil Production Fuel Combustion856 72 0.0 18 058 4 893 842Conventional Oil Production Fugitive Equipment Leaks


0 1 099 0.0 1 106 0 0Natural Gas Processing Fuel Combustion32 1 0.0 676 123 12Natural Gas Processing Fugitive Equipment Leaks45 0 0.0 948 144 7Natural Gas Processing Unreported Venting77 1 100 0.0 2 729 267 18Natural Gas Processing Sector Total









Nova Scotia

106

1994


Nova Scotia










Newfoundland

107

1994


Newfoundland




99 820 787 74.1 845 830 0 960Oil and Gas Well Drilling Fuel Combustion204 6 0.0 4 289 716 52Oil and Gas Well Drilling Reported Venting303 820 793 74.1 850 120 716 1 012Oil and Gas Well Drilling Sector Total











Canada

108

1994


Canada


289 941 3 724 131 147.5 9 858 610 1 682 250 306 968Conventional Oil Production Sector Total985 1 152 386 78.1 1 197 299 0 578Heavy Oil/Cold Bitumen Production Fuel Combustion471 758 733 0.0 768 626 0 386Heavy Oil/Cold Bitumen Production Flaring


304 275 129 191 0.0 6 518 958 1 010 446 58 132Heavy Oil/Cold Bitumen Production Reported Venting20 664 2 923 0.0 436 862 149 853 30 531Heavy Oil/Cold Bitumen Production Storage Losses97 028 1 711 0.0 2 039 307 311 478 15 351Heavy Oil/Cold Bitumen Production Unreported Venting













0 5 738 557 0.0 5 738 557 0 0Annual Total Formation CO2389 614 138 309 0.0 8 320 194 1 365 480 98 692Annual Total Reported Venting101 853 19 999 0.0 2 158 915 500 742 71 250Annual Total Surface Casing Vent Flow/Gas Migration

109

1994


Canada





110

1995


Yukon Territory


1 1 948 0.0 1 975 0 1Natural Gas Production Flaring24 1 0.0 509 81 5Natural Gas Production Fugitive Equipment Leaks16 0 0.0 344 53 3Natural Gas Production Unreported Venting42 1 949 0.0 2 828 134 9Natural Gas Production Sector Total16 10 125 1.0 10 767 0 9Natural Gas Processing Fuel Combustion9 2 0.0 198 31 2Natural Gas Processing Fugitive Equipment Leaks0 1 663 0.0 1 663 0 0Natural Gas Processing Formation CO2











111

1995

















British Columbia

112

1995


British Columbia




















Alberta

113

1995


Alberta



















114

1995


Alberta








30 603 3 915 0.0 646 575 570 863 161 334Annual Total Storage Losses321 757 6 003 0.0 6 762 889 1 036 988 52 272Annual Total Unreported Venting









770 151 0.0 16 330 3 718 539Conventional Oil Production Reported Venting1 001 91 0.0 21 108 74 523 23 822Conventional Oil Production Storage Losses

Saskatchewan

115

1995


Saskatchewan









10 616 4 0.0 222 950 33 606 1 517Thermal Operations Reported Venting735 53 0.0 15 490 5 106 1 009Thermal Operations Storage Losses












116

1995


Saskatchewan


6 331 410 0.0 133 367 116 981 32 957Annual Total Storage Losses63 894 1 097 0.0 1 342 871 205 017 10 078Annual Total Unreported Venting














Manitoba

117

1995


Ontario




0 1 675 0.1 1 713 0 0Conventional Oil Production Fuel Combustion856 72 0.0 18 058 4 893 842Conventional Oil Production Fugitive Equipment Leaks


0 1 170 0.0 1 177 0 0Natural Gas Processing Fuel Combustion34 1 0.0 719 131 12Natural Gas Processing Fugitive Equipment Leaks48 0 0.0 1 008 153 7Natural Gas Processing Unreported Venting82 1 171 0.0 2 904 284 20Natural Gas Processing Sector Total









Nova Scotia

118

1995


Nova Scotia










Newfoundland

119

1995


Newfoundland















Canada

120

1995


Canada


286 158 4 074 921 159.3 10 133 615 1 659 543 303 285Conventional Oil Production Sector Total1 031 1 225 600 82.3 1 272 742 0 605Heavy Oil/Cold Bitumen Production Fuel Combustion

499 803 289 0.0 813 772 0 409Heavy Oil/Cold Bitumen Production Flaring73 815 10 969 0.0 1 561 081 274 539 23 667Heavy Oil/Cold Bitumen Production Fugitive Equipment Leaks

170 37 0.0 3 615 819 118Heavy Oil/Cold Bitumen Production Glycol Dehydrator Off-Gas124 90 0.0 2 689 6 180 1 906Heavy Oil/Cold Bitumen Production Loading/Unloading

358 459 148 337 0.0 7 675 977 1 187 144 67 416Heavy Oil/Cold Bitumen Production Reported Venting23 340 3 283 0.0 493 419 169 204 34 465Heavy Oil/Cold Bitumen Production Storage Losses

110 350 1 946 0.0 2 319 304 354 242 17 459Heavy Oil/Cold Bitumen Production Unreported Venting567 788 2 193 551 82.3 14 142 598 1 992 128 146 045Heavy Oil/Cold Bitumen Production Sector Total

164 4 747 586 75.5 4 774 448 0 334Thermal Operations Fuel Combustion196 330 338 0.0 334 461 0 161Thermal Operations Flaring340 116 0.0 7 242 2 191 413Thermal Operations Fugitive Equipment Leaks


775 84 0.0 16 367 5 302 1 037Thermal Operations Storage Losses60 11 0.0 1 267 191 9Thermal Operations Unreported Venting











121

1995


Canada





122

1996


Yukon Territory


1 1 380 0.0 1 399 0 1Natural Gas Production Flaring23 1 0.0 491 78 5Natural Gas Production Fugitive Equipment Leaks16 0 0.0 332 51 2Natural Gas Production Unreported Venting40 1 381 0.0 2 223 129 8Natural Gas Production Sector Total15 9 550 0.9 10 156 0 9Natural Gas Processing Fuel Combustion

9 2 0.0 191 30 2Natural Gas Processing Fugitive Equipment Leaks0 1 605 0.0 1 605 0 0Natural Gas Processing Formation CO2











123

1996
















893 938 744 42.0 970 529 0 365Natural Gas Processing Fuel Combustion73 114 980 0.0 116 516 0 60Natural Gas Processing Flaring48 11 0.0 1 010 234 35Natural Gas Processing Glycol Dehydrator Off-Gas


British Columbia

124

1996


British Columbia





16 1 0.0 343 414 123Liquid Product Transportation Storage Losses17 696 0.0 1 046 419 125Liquid Product Transportation Sector Total















Alberta

125

1996


Alberta













44 33 0.0 953 213 30Thermal Operations Storage Losses48 12 0.0 1 015 153 7Thermal Operations Unreported Venting






126

1996


Alberta



76 394 15 000 0.0 1 619 272 368 650 53 440Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration54 548 10 707 0.0 1 156 218 268 299 39 812Accidents and Equipment Failures Spills/Pipeline Ruptures




76 394 15 000 0.0 1 619 272 368 650 53 440Annual Total Surface Casing Vent Flow/Gas Migration54 548 10 707 0.0 1 156 218 268 299 39 812Annual Total Spills/Pipeline Ruptures32 086 4 148 0.0 677 958 568 740 159 254Annual Total Storage Losses











Saskatchewan

127

1996


Saskatchewan





















128

1996


Saskatchewan






14 23 600 0.0 23 901 0 12Conventional Oil Production Flaring156 143 0.0 3 410 5 108 1 547Conventional Oil Production Fugitive Equipment Leaks107 101 0.0 2 357 3 245 988Conventional Oil Production Reported Venting56 5 0.0 1 186 4 224 1 351Conventional Oil Production Storage Losses

701 12 0.0 14 723 2 248 111Conventional Oil Production Unreported Venting1 039 35 345 0.7 57 379 14 826 4 011Conventional Oil Production Sector Total

0 0 0.0 1 5 2Liquid Product Transportation Fugitive Equipment Leaks19 1 0.0 391 472 140Liquid Product Transportation Storage Losses19 1 0.0 391 477 142Liquid Product Transportation Sector Total



14 23 600 0.0 23 901 0 12Annual Total Flaring156 143 0.0 3 411 5 114 1 549Annual Total Fugitive Equipment Leaks107 101 0.0 2 357 3 245 988Annual Total Reported Venting




Manitoba

129

1996


Ontario


1 9 127 0.8 9 396 0 10Oil and Gas Well Drilling Fuel Combustion1 9 127 0.8 9 396 0 10Oil and Gas Well Drilling Sector Total0 1 040 0.1 1 079 0 1Oil and Gas Well Servicing Fuel Combustion0 1 040 0.1 1 079 0 1Oil and Gas Well Servicing Sector Total1 596 0.0 628 0 0Natural Gas Production Fuel Combustion

241 4 0.0 5 071 794 45Natural Gas Production Fugitive Equipment Leaks92 1 0.0 1 932 294 14Natural Gas Production Unreported Venting

334 601 0.0 7 631 1 088 59Natural Gas Production Sector Total0 1 127 0.1 1 153 0 0Conventional Oil Production Fuel Combustion

856 72 0.0 18 058 4 893 842Conventional Oil Production Fugitive Equipment Leaks1 021 18 0.0 21 459 3 277 161Conventional Oil Production Unreported Venting1 877 1 217 0.1 40 669 8 170 1 004Conventional Oil Production Sector Total

0 787 0.0 792 0 0Natural Gas Processing Fuel Combustion23 0 0.0 484 88 8Natural Gas Processing Fugitive Equipment Leaks32 0 0.0 678 103 5Natural Gas Processing Unreported Venting55 788 0.0 1 954 191 13Natural Gas Processing Sector Total









Nova Scotia

130

1996


Nova Scotia










Newfoundland

131

1996


Newfoundland




108 894 985 80.8 922 302 0 1 052Oil and Gas Well Drilling Fuel Combustion221 6 0.0 4 644 776 57Oil and Gas Well Drilling Reported Venting329 894 991 80.8 926 946 776 1 109Oil and Gas Well Drilling Sector Total











Canada

132

1996


Canada









858 92 0.0 18 116 5 871 1 149Thermal Operations Storage Losses65 12 0.0 1 384 209 10Thermal Operations Unreported Venting











133

1996


Canada


54 740 10 724 0.0 1 160 258 298 015 49 337Annual Total Spills/Pipeline Ruptures39 552 4 637 0.0 835 236 722 263 204 682Annual Total Storage Losses



134

1997


Yukon Territory


2 2 404 0.0 2 437 0 1Natural Gas Production Flaring22 1 0.0 465 74 4Natural Gas Production Fugitive Equipment Leaks15 0 0.0 314 48 2Natural Gas Production Unreported Venting39 2 405 0.0 3 217 122 8Natural Gas Production Sector Total16 10 008 1.0 10 643 0 9Natural Gas Processing Fuel Combustion9 2 0.0 181 28 2Natural Gas Processing Fugitive Equipment Leaks0 1 518 0.0 1 518 0 0Natural Gas Processing Formation CO2








41 8 0.0 862 216 35Conventional Oil Production Fugitive Equipment Leaks20 5 0.0 433 105 16Conventional Oil Production Glycol Dehydrator Off-Gas38 7 0.0 800 182 26Conventional Oil Production Unreported Venting




135

1997




20 5 0.0 433 105 16Annual Total Glycol Dehydrator Off-Gas2 3 978 0.0 4 028 0 2Annual Total Flaring

41 8 0.0 863 216 35Annual Total Fugitive Equipment Leaks3 1 0.0 64 15 2Annual Total Surface Casing Vent Flow/Gas Migration1 0 0.0 14 99 32Annual Total Spills/Pipeline Ruptures












953 1 002 048 44.9 1 035 977 0 390Natural Gas Processing Fuel Combustion71 111 872 0.0 113 366 0 58Natural Gas Processing Flaring49 11 0.0 1 036 239 35Natural Gas Processing Glycol Dehydrator Off-Gas


British Columbia

136

1997


British Columbia





19 1 0.0 391 473 141Liquid Product Transportation Storage Losses19 677 0.0 1 076 478 142Liquid Product Transportation Sector Total




15 1 0.0 324 3 320 1 075Annual Total Loading/Unloading0 2 049 723 0.0 2 049 723 0 0Annual Total Formation CO2



17 669 453 0.0 371 499 56 612 2 760Annual Total Unreported Venting52 4 0.0 1 099 182 13Annual Total Reported Venting





431 661 330 0.0 670 373 0 353Well Testing Flaring4 261 74 0.0 89 562 13 675 673Well Testing Reported Venting4 692 661 404 0.0 759 935 13 675 1 025Well Testing Sector Total



Alberta

137

1997


Alberta




2 234 1 288 752 129.5 1 375 819 0 1 119Conventional Oil Production Fuel Combustion883 1 446 589 0.0 1 465 122 0 723Conventional Oil Production Flaring




223 244 2 752 453 129.5 7 480 737 1 234 377 211 743Conventional Oil Production Sector Total1 123 791 465 75.4 838 432 0 631Heavy Oil/Cold Bitumen Production Fuel Combustion






52 39 0.0 1 130 252 36Thermal Operations Storage Losses57 14 0.0 1 204 181 9Thermal Operations Unreported Venting





54 070 14 718 149 575.4 16 031 990 166 483 27 305Natural Gas Processing Sector Total5 9 531 0.0 9 641 0 4Liquid Product Transportation Flaring1 0 0.0 31 183 58Liquid Product Transportation Fugitive Equipment Leaks

10 0 0.0 204 31 2Liquid Product Transportation Reported Venting

138

1997


Alberta



86 231 16 931 0.0 1 827 777 416 119 60 321Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration12 847 2 522 0.0 272 313 63 190 9 377Accidents and Equipment Failures Spills/Pipeline Ruptures99 078 19 453 0.0 2 100 090 479 309 69 698Accidents and Equipment Failures Sector Total43 542 25 108 095 1 626.0 26 526 527 0 16 382Annual Total Fuel Combustion34 056 5 482 0.0 720 664 148 440 18 459Annual Total Glycol Dehydrator Off-Gas2 368 3 787 784 0.0 3 837 506 0 1 939Annual Total Flaring



86 231 16 931 0.0 1 827 777 416 119 60 321Annual Total Surface Casing Vent Flow/Gas Migration12 847 2 522 0.0 272 313 63 190 9 377Annual Total Spills/Pipeline Ruptures32 291 4 197 0.0 682 311 553 848 154 119Annual Total Storage Losses







1 632 95 0.0 34 371 5 713 416Natural Gas Production Glycol Dehydrator Off-Gas21 089 459 0.0 443 319 70 007 4 103Natural Gas Production Fugitive Equipment Leaks12 629 213 0.0 265 416 40 512 1 989Natural Gas Production Unreported Venting35 821 312 746 28.2 1 073 744 116 232 6 774Natural Gas Production Sector Total




Saskatchewan

139

1997


Saskatchewan






48 899 849 0.0 1 027 728 156 927 7 721Heavy Oil/Cold Bitumen Production Unreported Venting337 864 604 035 17.7 7 704 658 1 074 255 48 994Heavy Oil/Cold Bitumen Production Sector Total



15 074 5 0.0 316 567 47 718 2 154Thermal Operations Reported Venting1 044 76 0.0 21 994 7 251 1 433Thermal Operations Storage Losses







46 647 9 157 0.0 988 753 228 020 33 583Accidents and Equipment Failures Sector Total2 317 1 699 113 100.6 1 778 962 0 1 040Annual Total Fuel Combustion1 648 99 0.0 34 705 5 793 428Annual Total Glycol Dehydrator Off-Gas





140

1997


Saskatchewan
















Manitoba

141

1997


Ontario




293 526 0.0 6 687 953 52Natural Gas Production Sector Total0 987 0.1 1 010 0 0Conventional Oil Production Fuel Combustion

856 72 0.0 18 058 4 893 842Conventional Oil Production Fugitive Equipment Leaks841 15 0.0 17 670 2 698 133Conventional Oil Production Unreported Venting

1 697 1 074 0.1 36 738 7 591 975Conventional Oil Production Sector Total0 690 0.0 694 0 0Natural Gas Processing Fuel Combustion

20 0 0.0 424 77 7Natural Gas Processing Fugitive Equipment Leaks28 0 0.0 595 90 4Natural Gas Processing Unreported Venting48 690 0.0 1 712 167 12Natural Gas Processing Sector Total






51 2 0.0 1 080 1 305 388Annual Total Storage Losses950 15 0.0 19 958 3 046 149Annual Total Unreported Venting




Nova Scotia

142

1997


Nova Scotia






42 4 0.0 887 0 968Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting




Newfoundland

143

1997


Newfoundland




141 1 169 506 105.4 1 205 141 0 1 364Oil and Gas Well Drilling Fuel Combustion295 8 0.0 6 208 1 033 75Oil and Gas Well Drilling Reported Venting437 1 169 514 105.4 1 211 349 1 033 1 438Oil and Gas Well Drilling Sector Total











Canada

144

1997


Canada








1 0 0.0 30 288 93Thermal Operations Loading/Unloading33 883 2 189 0.0 713 724 118 459 8 513Thermal Operations Reported Venting1 096 115 0.0 23 124 7 503 1 469Thermal Operations Storage Losses

79 14 0.0 1 676 253 12Thermal Operations Unreported Venting35 891 5 853 869 87.6 6 634 719 129 401 11 170Thermal Operations Sector Total17 884 10 970 832 625.6 11 540 319 0 5 715Natural Gas Processing Fuel Combustion





10 0 0.0 204 31 2Liquid Product Transportation Reported Venting1 285 55 0.0 27 042 42 463 12 955Liquid Product Transportation Storage Losses1 303 10 405 0.0 37 761 42 783 13 054Liquid Product Transportation Sector Total

140 124 27 513 0.0 2 970 124 690 428 98 022Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration13 039 2 539 0.0 276 353 92 906 18 902Accidents and Equipment Failures Spills/Pipeline Ruptures




145

1997


Canada


13 039 2 539 0.0 276 353 92 906 18 902Annual Total Spills/Pipeline Ruptures41 426 4 789 0.0 874 737 725 012 203 471Annual Total Storage Losses



146

1998


Yukon Territory















147

1998










2 416 1 097 240 106.4 1 180 962 0 974Natural Gas Production Fuel Combustion47 71 303 0.0 72 290 0 38Natural Gas Production Flaring



30 290 1 169 983 106.4 1 839 056 95 933 7 620Natural Gas Production Sector Total465 261 008 27.9 279 401 0 256Conventional Oil Production Fuel Combustion179 293 752 0.0 297 517 0 147Conventional Oil Production Flaring



8 829 146 0.0 185 563 28 314 1 387Conventional Oil Production Unreported Venting17 764 556 264 27.9 937 942 92 839 15 677Conventional Oil Production Sector Total1 145 1 203 974 53.9 1 244 740 0 469Natural Gas Processing Fuel Combustion



British Columbia

148

1998


British Columbia










1 010 165 0.0 21 384 4 576 606Annual Total Reported Venting3 375 663 0.0 71 538 32 573 2 361Annual Total Surface Casing Vent Flow/Gas Migration






161 520 522 47.3 538 579 359 650Oil and Gas Well Drilling Sector Total5 434 126 725 16.0 245 785 0 1 065Oil and Gas Well Servicing Fuel Combustion5 434 126 725 16.0 245 785 0 1 065Oil and Gas Well Servicing Sector Total




Alberta

149

1998


Alberta






54 7 0.0 1 146 9 355 3 006Conventional Oil Production Loading/Unloading45 723 5 763 0.0 965 952 202 884 26 000Conventional Oil Production Reported Venting














10 0 0.0 202 31 2Liquid Product Transportation Reported Venting

150

1998


Alberta







94 228 18 501 0.0 1 997 295 454 712 65 916Annual Total Surface Casing Vent Flow/Gas Migration56 528 11 095 0.0 1 198 180 278 036 41 257Annual Total Spills/Pipeline Ruptures30 911 3 980 0.0 653 110 527 789 146 753Annual Total Storage Losses











Saskatchewan

151

1998


Saskatchewan






46 747 811 0.0 982 488 150 019 7 381Heavy Oil/Cold Bitumen Production Unreported Venting329 014 602 560 17.3 7 517 224 1 044 807 47 293Heavy Oil/Cold Bitumen Production Sector Total









50 114 9 840 0.0 1 062 234 241 832 35 056Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration19 2 0.0 409 3 010 965Accidents and Equipment Failures Spills/Pipeline Ruptures

50 133 9 841 0.0 1 062 643 244 842 36 021Accidents and Equipment Failures Sector Total1 486 1 546 190 87.1 1 604 402 0 748Annual Total Fuel Combustion1 620 97 0.0 34 114 5 693 421Annual Total Glycol Dehydrator Off-Gas



266 523 967 0.0 5 597 955 795 330 21 389Annual Total Reported Venting50 114 9 840 0.0 1 062 234 241 832 35 056Annual Total Surface Casing Vent Flow/Gas Migration


152

1998


Saskatchewan
















Manitoba

153

1998


Ontario




300 539 0.0 6 848 976 53Natural Gas Production Sector Total0 1 011 0.1 1 034 0 0Conventional Oil Production Fuel Combustion

856 72 0.0 18 058 4 893 842Conventional Oil Production Fugitive Equipment Leaks833 14 0.0 17 510 2 674 132Conventional Oil Production Unreported Venting

1 690 1 098 0.1 36 602 7 567 974Conventional Oil Production Sector Total0 706 0.0 711 0 0Natural Gas Processing Fuel Combustion

21 0 0.0 434 79 7Natural Gas Processing Fugitive Equipment Leaks29 0 0.0 609 92 4Natural Gas Processing Unreported Venting50 707 0.0 1 754 171 12Natural Gas Processing Sector Total






51 2 0.0 1 070 1 293 384Annual Total Storage Losses945 15 0.0 19 853 3 030 149Annual Total Unreported Venting




Nova Scotia

154

1998


Nova Scotia




254 23 0.0 5 359 0 5 848Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fuel Combustion0 0 0.0 0 0 0Natural Gas Processing Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Processing Sector Total

10 2 0.0 202 46 7Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration10 2 0.0 202 46 7Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Annual Total Flaring

202 18 0.0 4 265 0 4 654Annual Total Fugitive Equipment Leaks10 2 0.0 202 46 7Annual Total Surface Casing Vent Flow/Gas Migration52 5 0.0 1 094 0 1 194Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting



0 0 0.0 0 0 0Oil and Gas Well Drilling Fuel Combustion0 0 0.0 0 0 0Oil and Gas Well Drilling Sector Total0 0 0.0 7 1 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 7 1 0Natural Gas Production Sector Total

13 198 010 4.7 199 727 0 4Conventional Oil Production Fuel Combustion1 250 2 010 001 0.0 2 036 260 0 1 024Conventional Oil Production Flaring

68 3 0.0 1 431 324 46Conventional Oil Production Fugitive Equipment Leaks21 2 0.0 438 3 219 1 032Conventional Oil Production Loading/Unloading

319 29 0.0 6 736 23 989 7 670Conventional Oil Production Storage Losses12 1 0.0 246 53 7Conventional Oil Production Unreported Venting

1 683 2 208 046 4.7 2 244 838 27 585 9 783Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks

Newfoundland

155

1998


Newfoundland


0 0 0.0 0 0 0Natural Gas Processing Sector Total0 0 0.0 2 12 4Accidents and Equipment Failures Spills/Pipeline Ruptures0 0 0.0 2 12 4Accidents and Equipment Failures Sector Total

13 198 010 4.7 199 727 0 4Annual Total Fuel Combustion1 250 2 010 001 0.0 2 036 260 0 1 024Annual Total Flaring

68 3 0.0 1 438 326 46Annual Total Fugitive Equipment Leaks21 2 0.0 438 3 219 1 032Annual Total Loading/Unloading0 0 0.0 2 12 4Annual Total Spills/Pipeline Ruptures

319 29 0.0 6 736 23 989 7 670Annual Total Storage Losses12 1 0.0 246 53 7Annual Total Unreported Venting














Canada

156

1998


Canada














10 0 0.0 202 31 2Liquid Product Transportation Reported Venting1 275 54 0.0 26 838 42 145 12 858Liquid Product Transportation Storage Losses1 292 9 093 0.0 36 228 42 463 12 955Liquid Product Transportation Sector Total


208 900 40 993 0.0 4 427 889 1 058 419 157 241Accidents and Equipment Failures Sector Total46 580 29 943 029 1 925.4 31 518 089 0 18 385Annual Total Fuel Combustion41 127 6 547 0.0 870 220 178 646 22 086Annual Total Glycol Dehydrator Off-Gas4 148 6 653 466 0.0 6 740 583 0 3 396Annual Total Flaring



157

1998


Canada


56 719 11 113 0.0 1 202 222 307 765 50 786Annual Total Spills/Pipeline Ruptures40 089 4 585 0.0 846 450 723 050 204 304Annual Total Storage Losses



158

1999


Yukon Territory






48 4 0.0 1 004 158 9Annual Total Fugitive Equipment Leaks0 2 360 0.0 2 360 0 0Annual Total Formation CO26 1 0.0 123 28 4Annual Total Surface Casing Vent Flow/Gas Migration









159

1999



















British Columbia

160

1999


British Columbia




















Alberta

161

1999


Alberta




















162

1999


Alberta








309 787 5 821 0.0 6 511 348 998 609 50 393Annual Total Unreported Venting3 165 55 0.0 66 526 10 209 516Annual Total Reported Venting










Saskatchewan

163

1999


Saskatchewan






46 604 809 0.0 979 500 149 563 7 359Heavy Oil/Cold Bitumen Production Unreported Venting334 001 614 092 18.2 7 633 773 1 059 415 47 591Heavy Oil/Cold Bitumen Production Sector Total










55 066 10 810 0.0 1 167 200 268 646 39 472Accidents and Equipment Failures Sector Total1 807 1 666 027 95.3 1 733 524 0 871Annual Total Fuel Combustion1 666 100 0.0 35 088 5 855 432Annual Total Glycol Dehydrator Off-Gas



271 617 965 0.0 5 704 932 810 266 21 708Annual Total Reported Venting55 047 10 808 0.0 1 166 791 265 636 38 507Annual Total Surface Casing Vent Flow/Gas Migration


164

1999


Saskatchewan






14 22 259 0.0 22 544 0 11Conventional Oil Production Flaring156 143 0.0 3 410 5 108 1 547Conventional Oil Production Fugitive Equipment Leaks101 95 0.0 2 223 3 060 932Conventional Oil Production Reported Venting53 5 0.0 1 119 3 984 1 274Conventional Oil Production Storage Losses

661 11 0.0 13 887 2 120 104Conventional Oil Production Unreported Venting988 33 345 0.7 54 313 14 274 3 871Conventional Oil Production Sector Total

0 0 0.0 1 5 2Liquid Product Transportation Fugitive Equipment Leaks18 1 0.0 368 445 132Liquid Product Transportation Storage Losses18 1 0.0 369 450 134Liquid Product Transportation Sector Total



14 22 259 0.0 22 544 0 11Annual Total Flaring156 143 0.0 3 411 5 113 1 549Annual Total Fugitive Equipment Leaks101 95 0.0 2 223 3 060 932Annual Total Reported Venting




Manitoba

165

1999


Ontario















Nova Scotia

166

1999


Nova Scotia




221 20 0.0 4 664 0 5 090Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fuel Combustion0 0 0.0 0 0 0Natural Gas Processing Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks0 0 0.0 0 0 0Natural Gas Processing Sector Total

10 2 0.0 211 48 7Accidents and Equipment Failures Surface Casing Vent Flow/Gas Migration10 2 0.0 211 48 7Accidents and Equipment Failures Sector Total0 0 0.0 0 0 0Annual Total Fuel Combustion0 0 0.0 0 0 0Annual Total Glycol Dehydrator Off-Gas0 0 0.0 0 0 0Annual Total Flaring

202 18 0.0 4 265 0 4 654Annual Total Fugitive Equipment Leaks10 2 0.0 211 48 7Annual Total Surface Casing Vent Flow/Gas Migration19 2 0.0 399 0 436Annual Total Storage Losses0 0 0.0 0 0 0Annual Total Unreported Venting




18 278 901 6.6 281 320 0 6Conventional Oil Production Fuel Combustion554 890 852 0.0 902 491 0 454Conventional Oil Production Flaring68 3 0.0 1 431 324 46Conventional Oil Production Fugitive Equipment Leaks32 3 0.0 669 4 922 1 578Conventional Oil Production Loading/Unloading


1 178 1 169 804 6.6 1 196 586 42 009 13 823Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks

Newfoundland

167

1999


Newfoundland



18 279 113 6.6 281 540 0 7Annual Total Fuel Combustion554 890 852 0.0 902 491 0 454Annual Total Flaring69 3 0.0 1 442 326 46Annual Total Fugitive Equipment Leaks32 3 0.0 669 4 922 1 578Annual Total Loading/Unloading0 0 0.0 2 12 4Annual Total Spills/Pipeline Ruptures















Canada

168

1999


Canada



















169

1999


Canada





170

2000


Yukon Territory


0 401 0.0 406 0 0Natural Gas Production Flaring31 1 0.0 655 104 6Natural Gas Production Fugitive Equipment Leaks21 0 0.0 443 68 3Natural Gas Production Unreported Venting52 402 0.0 1 504 172 10Natural Gas Production Sector Total17 10 666 1.0 11 343 0 10Natural Gas Processing Fuel Combustion12 3 0.0 255 39 2Natural Gas Processing Fugitive Equipment Leaks







0 4 038 0.4 4 161 0 5Oil and Gas Well Drilling Fuel Combustion0 4 038 0.4 4 161 0 5Oil and Gas Well Drilling Sector Total0 437 0.1 454 0 1Oil and Gas Well Servicing Fuel Combustion0 437 0.1 454 0 1Oil and Gas Well Servicing Sector Total0 0 0.0 4 1 0Natural Gas Production Fugitive Equipment Leaks0 0 0.0 4 1 0Natural Gas Production Sector Total9 173 879 4.4 175 449 0 5Conventional Oil Production Fuel Combustion4 7 209 0.0 7 301 0 4Conventional Oil Production Flaring





171

2000









100 233 323 21.2 242 009 250 296Oil and Gas Well Drilling Sector Total183 10 799 1.4 15 076 0 47Oil and Gas Well Servicing Fuel Combustion183 10 799 1.4 15 076 0 47Oil and Gas Well Servicing Sector Total127 200 457 0.0 203 130 0 104Well Testing Flaring127 200 457 0.0 203 130 0 104Well Testing Sector Total










British Columbia

172

2000


British Columbia




















Alberta

173

2000


Alberta






46 6 0.0 965 7 879 2 532Conventional Oil Production Loading/Unloading38 508 4 853 0.0 813 530 170 870 21 898Conventional Oil Production Reported Venting














174

2000


Alberta







87 334 17 148 0.0 1 851 153 421 440 61 093Annual Total Surface Casing Vent Flow/Gas Migration39 354 7 725 0.0 834 167 193 567 28 723Annual Total Spills/Pipeline Ruptures29 375 3 775 0.0 620 655 471 711 129 558Annual Total Storage Losses

304 454 5 729 0.0 6 399 271 981 471 49 542Annual Total Unreported Venting4 535 79 0.0 95 322 14 627 740Annual Total Reported Venting






1 701 99 0.0 35 823 5 954 433Natural Gas Production Glycol Dehydrator Off-Gas21 979 478 0.0 462 045 72 964 4 276Natural Gas Production Fugitive Equipment Leaks13 162 222 0.0 276 627 42 223 2 073Natural Gas Production Unreported Venting37 364 344 692 31.2 1 139 011 121 141 7 076Natural Gas Production Sector Total




Saskatchewan

175

2000


Saskatchewan





325 254 1 017 0.0 6 831 350 965 067 24 215Heavy Oil/Cold Bitumen Production Reported Venting7 234 430 0.0 152 341 50 695 10 079Heavy Oil/Cold Bitumen Production Storage Losses

57 759 1 002 0.0 1 213 938 185 360 9 120Heavy Oil/Cold Bitumen Production Unreported Venting421 348 654 224 19.5 9 508 592 1 335 022 59 514Heavy Oil/Cold Bitumen Production Sector Total



17 806 6 0.0 373 925 56 363 2 544Thermal Operations Reported Venting1 233 89 0.0 25 979 8 564 1 693Thermal Operations Storage Losses







61 607 12 094 0.0 1 305 840 300 209 44 047Accidents and Equipment Failures Sector Total2 336 1 845 277 108.0 1 927 801 0 1 072Annual Total Fuel Combustion1 720 104 0.0 36 214 6 048 448Annual Total Glycol Dehydrator Off-Gas



343 883 1 185 0.0 7 222 734 1 025 405 27 335Annual Total Reported Venting61 588 12 093 0.0 1 305 431 297 199 43 083Annual Total Surface Casing Vent Flow/Gas Migration


176

2000


Saskatchewan
















Manitoba

177

2000


Ontario


2 21 600 1.9 22 236 0 25Oil and Gas Well Drilling Fuel Combustion2 21 600 1.9 22 236 0 25Oil and Gas Well Drilling Sector Total0 2 462 0.3 2 554 0 4Oil and Gas Well Servicing Fuel Combustion0 2 462 0.3 2 554 0 4Oil and Gas Well Servicing Sector Total2 1 126 0.1 1 186 0 1Natural Gas Production Fuel Combustion

456 7 0.0 9 581 1 500 84Natural Gas Production Fugitive Equipment Leaks174 2 0.0 3 650 555 27Natural Gas Production Unreported Venting631 1 135 0.1 14 417 2 055 112Natural Gas Production Sector Total



43 1 0.0 914 166 16Natural Gas Processing Fugitive Equipment Leaks61 0 0.0 1 282 194 9Natural Gas Processing Unreported Venting

105 1 488 0.0 3 692 361 25Natural Gas Processing Sector Total0 45 0.0 46 0 0Liquid Product Transportation Flaring0 0 0.0 2 14 4Liquid Product Transportation Fugitive Equipment Leaks







1 3 927 0.4 4 072 0 6Oil and Gas Well Drilling Fuel Combustion1 3 927 0.4 4 072 0 6Oil and Gas Well Drilling Sector Total0 57 0.0 60 0 0Oil and Gas Well Servicing Fuel Combustion0 57 0.0 60 0 0Oil and Gas Well Servicing Sector Total

Nova Scotia

178

2000


Nova Scotia



1 252 23 0.0 26 321 3 966 179Natural Gas Production Glycol Dehydrator Off-Gas87 2 0.0 1 819 289 18Natural Gas Production Fugitive Equipment Leaks63 1 0.0 1 328 203 10Natural Gas Production Unreported Venting

1 456 44 760 2.2 76 019 4 458 241Natural Gas Production Sector Total0 0 0.0 0 0 0Conventional Oil Production Fugitive Equipment Leaks0 0 0.0 0 0 0Conventional Oil Production Storage Losses0 0 0.0 0 0 0Conventional Oil Production Sector Total

207 214 309 13.8 222 941 0 122Natural Gas Processing Fuel Combustion6 2 0.0 128 31 5Natural Gas Processing Glycol Dehydrator Off-Gas

59 1 0.0 1 237 316 51Natural Gas Processing Fugitive Equipment Leaks272 214 311 13.8 224 305 346 178Natural Gas Processing Sector Total


246 237 584 16.4 247 832 0 148Annual Total Fuel Combustion1 258 24 0.0 26 448 3 996 184Annual Total Glycol Dehydrator Off-Gas

17 25 443 0.0 25 793 0 14Annual Total Flaring145 3 0.0 3 055 605 69Annual Total Fugitive Equipment Leaks10 2 0.0 219 50 7Annual Total Surface Casing Vent Flow/Gas Migration0 0 0.0 0 0 0Annual Total Storage Losses

63 1 0.0 1 328 203 10Annual Total Unreported Venting1 740 263 058 16.4 304 676 4 854 432Annual Total Sector Total



22 341 678 8.1 344 642 0 8Conventional Oil Production Fuel Combustion144 231 026 0.0 234 044 0 118Conventional Oil Production Flaring68 3 0.0 1 431 324 46Conventional Oil Production Fugitive Equipment Leaks46 4 0.0 971 7 141 2 289Conventional Oil Production Loading/Unloading


1 014 572 777 8.1 596 577 60 802 19 491Conventional Oil Production Sector Total0 0 0.0 0 0 0Natural Gas Processing Fugitive Equipment Leaks

Newfoundland

179

2000


Newfoundland



22 341 929 8.1 344 902 0 8Annual Total Fuel Combustion144 231 026 0.0 234 044 0 118Annual Total Flaring69 3 0.0 1 450 328 46Annual Total Fugitive Equipment Leaks46 4 0.0 971 7 141 2 289Annual Total Loading/Unloading0 0 0.0 2 12 4Annual Total Spills/Pipeline Ruptures




152 1 256 511 113.4 1 294 862 0 1 474Oil and Gas Well Drilling Fuel Combustion314 10 0.0 6 604 1 100 80Oil and Gas Well Drilling Reported Venting466 1 256 521 113.4 1 301 466 1 100 1 554Oil and Gas Well Drilling Sector Total











Canada

180

2000


Canada
















198 015 38 857 0.0 4 197 180 1 010 705 149 107Accidents and Equipment Failures Sector Total53 923 32 869 227 2 127.5 34 661 148 0 21 073Annual Total Fuel Combustion42 975 6 633 0.0 909 109 184 939 22 499Annual Total Glycol Dehydrator Off-Gas3 079 4 921 586 0.0 4 986 252 0 2 521Annual Total Flaring



181

2000


Canada





182

Carbon Dioxide

Table 11.2. GHG emission summaries for the oil industry in the UNFCC common reporting format (CRF)

Emissions (t/y)

Source Category Oil Exploration Oil Production Oil Transportation

Flaring 887 218.9 3 266 380.4 8 961.1 Fuel Combustion 1 246 981.4 10 245 176.6 Fugitive 9.8 70 386.4 51.8 Other Venting 75.8 171 991.0Total 2 134 285.8 13 753 934.5 9 013.0


Flaring 4.2 2.5 24.2 Fuel Combustion 0.7 5.6 Fugitive 14.4 13.3 16.9 Other Venting 38.4 9.0Total 1.8 4.2 24.1

Lower Uncertainty (%)



Upper Uncertainty (%)

183

Carbon Dioxide Equivalent


Emissions (t/y)


Flaring 899 266.5 3 528 346.6 9 064.7 Fuel Combustion 1 285 218.0 10 483 042.3 Fugitive 6 604.3 13 583 326.9 25 864.9 Other Venting 91 715.1 12 967 419.2Total 2 282 803.8 40 562 135.0 34 929.6







184

Carbon Dioxide Oxidation


Emissions (t/y)


Fugitive 1 100.2 3 260 224.8 40 138.0 Other Venting 14 004.3 2 026 144.2Total 15 104.5 5 286 369.1 40 138.0


Fugitive 7.2 4.4 7.1 Other Venting 33.1 3.1Total 30.7 3.0 7.1



Fugitive 6.7 4.4 7.1 Other Venting 26.4 2.9Total 24.4 2.9 7.1


185

Methane


Emissions (t/y)


Flaring 573.7 12 474.6 4.9 Fuel Combustion 146.7 4 789.3 Fugitive 314.0 643 473.8 1 229.2 Venting 4 363.8 609 306.1Total 5 398.2 1 270 043.8 1 234.1


Flaring 16.7 1.4 88.7 Fuel Combustion 1.6 5.0 Fugitive 8.9 7.4 21.0 Venting 38.4 3.7Total 31.1 4.2 20.9



Flaring 16.7 1.6 99.8 Fuel Combustion 1.6 5.2 Fugitive 8.4 7.4 21.1 Venting 30.5 3.5Total 24.7 4.1 21.0


186

Nitrous Oxide


Emissions (t/y)


Flaring Fuel Combustion 113.4 442.9Total 113.4 442.9







187

Non Methane VOCs


Emissions (t/y)


Flaring 469.7 3 293.7 4.0 Fuel Combustion 1 469.8 3 348.8 Fugitive 79.9 489 773.5 12 231.4 Other Venting 689.0 117 807.7Total 2 708.4 614 223.6 12 235.4







188

Carbon Dioxide

Table 11.3. GHG emission summaries for the natural gas industry in the UNFCC common reporting format (CRF)

Emissions (t/y)

Source Category Gas Exploration

Gas Production/ Processing

Gas Transmission

Gas Storage Gas Distribution

Flaring 768 737.0 Fuel Combustion 21 367 357.5 12 011 513.0 40 271.0 80 698.0 Fugitive 19 659.6 146.0 16.0 2 384.0 Other 6 813 156.2 Venting 295.9 528.0 2.0 75.0Total 28 969 206.1 12 012 187.0 40 289.0 83 157.0



Gas Transmission


Flaring 2.6 Fuel Combustion 1.1 Fugitive 1.5 Other 1.7 Venting 6.1Total 0.9




Gas Transmission




189

Carbon Dioxide Equivalent


Emissions (t/y)



Gas Transmission


Flaring 779 293.5 Fuel Combustion 22 663 169.0 12 285 701.0 41 653.0 81 442.0 Fugitive 11 063 175.6 1 968 725.0 71 258.0 987 929.0 Other 6 813 156.2 Venting 156 533.3 1 308 231.0 15 651.0 96 007.0Total 41 475 327.6 15 562 657.0 128 562.0 1 165 378.0



Gas Transmission






Gas Transmission




190

Carbon Dioxide Oxidation


Emissions (t/y)



Gas Transmission


Fugitive 1 867 244.2 Other Venting 25 272.4Total 1 892 516.6



Gas Transmission


Fugitive 0.5 Other Venting 3.2Total 0.5




Gas Transmission


Fugitive 0.9 Other Venting 2.9Total 0.9


191

Methane


Emissions (t/y)



Gas Transmission


Flaring 502.7 Fuel Combustion 38 510.5 2 857.0 31.0 7.0 Fugitive 525 881.7 93 743.0 3 392.0 46 931.0 Venting 7 439.9 62 271.0 745.0 4 569.0Total 572 334.8 96 600.0 4 168.0 51 507.0



Gas Transmission


Flaring 7.9 Fuel Combustion 2.8 Fugitive 0.6 Venting 4.0Total 0.6




Gas Transmission


Flaring 8.5 Fuel Combustion 2.8 Fugitive 1.1 Venting 3.5Total 1.0


192

Nitrous Oxide


Emissions (t/y)



Gas Transmission


Flaring Fuel Combustion 1 571.3 690.0 2.0 1.0Total 1 571.3 690.0 2.0 1.0



Gas Transmission


Flaring Fuel Combustion 1.0Total 1.0




Gas Transmission


Flaring Fuel Combustion 16.4Total 16.4


193

Non Methane VOCs


Emissions (t/y)



Gas Transmission


Flaring 411.6 Fuel Combustion 14 596.6 Fugitive 142 807.9 Other Venting 1 637.5Total 159 453.6



Gas Transmission


Flaring 14.7 Fuel Combustion 11.0 Fugitive 3.1 Other Venting 25.7Total 3.0




Gas Transmission


Flaring 35.8 Fuel Combustion 11.1 Fugitive 5.7 Other Venting 22.9Total 5.2


194

195

12.0 APPENDIX D: GRAPHICAL SUMMARY OF THE INVENTORY BY PROVINCE

The histograms presented in this appendix show the relative distribution of each target GHG and pollutant by province.

196

Carbon Dioxide Equivalent Emissions Presented by Province Total Emissions = 84 355 kt/y

0

10 000 000

20 000 000

30 000 000

40 000 000

50 000 000

60 000 000

70 000 000

AB BC MB NL NS NT ON SK YT

Province

Em

issi

on

s (t

/y)

Carbon Dioxide Emissions Presented by Province Total Emissions = 44 866 kt/y

0

5 000 000

10 000 000

15 000 000

20 000 000

25 000 000

30 000 000

35 000 000

40 000 000


Province

Em

issi

on

s (t

/y)

Figure 10 Histogram depicting CO2 equivalent emissions by province and territory.

Figure 11 Histogram depicting CO2 emissions by province and territory.

Methane Emissions Presented by Province Total Emissions = 1 849 kt/y

0

200 000

400 000

600 000

800 000

1 000 000

1 200 000

1 400 000


Province

Em

issi

on

s (t

/y)

Nitrous Oxide Emissions Presented by Province Total Emissions = 2.13 kt/y

0

200

400

600

800

1 000

1 200

1 400

1 600

1 800

2 000


Province

Em

issi

on

s (t

/y)

Figure 12 Histogram depicting CH4 emissions by province and territory. Figure 13 Histogram depicting N2O emissions by province and territory.

197

CO2 Atmospheric Oxidation Emissions Presented by Province Total Emissions = 7 234 kt/y

0

1 000 000

2 000 000

3 000 000

4 000 000

5 000 000

6 000 000


Province

Em

issi

on

s (t

/y)

Figure 14 Histogram depicting atmospheric CO2 emissions by province and territory.

198

13.0 APPENDIX E: GHG EMISSION INTENSITY PLOTS BY TYPE OF FACILITY The following graphs present the cumulative GHG emissions, plotted as a function of the cumulative production for individual types of facilities. The vertical lines drawn through the plotted points depict their associated confidence limits. For each sector four graphs are presented:

1. Emission intensity based on total facility emissions vs. cumulative production as a percentage of total.

2. Emission intensity based on total facility emissions vs. cumulative emissions as a percentage of total.

3. Emission intensity based on covered facility emissions vs. cumulative production as a percentage of total.

4. Emission intensity based on covered facility emissions vs. cumulative emissions as a percentage of total.

Total emissions include all sources of GHG emissions at the site while covered emissions include fuel combustion, flaring, formation CO2 emissions and reported venting. The denominator of the intensity calculation is:

• Natural Gas Processing – sum of sales products on an equivalent energy basis as m3 of equivalent light/medium oil plus the volume of formation CO2.

• Natural Gas Production – total natural gas receipts to the inlet of the facility in 103 m3.

• Light/Medium Crude Oil Production – sum of crude oil and natural gas production on an equivalent energy basis as m3 of equivalent light/medium oil.

• Cold Heavy Crude Oil/Bitumen Production – sum of crude oil and natural gas production on an equivalent energy basis as m3 of equivalent light/medium oil.

• Thermal Heavy Crude Oil/Bitumen Production – sum of crude oil and natural gas production on an equivalent energy basis as m3 of equivalent light/medium oil.

Each of the presented graphs has a point for each facility’s intensity (the blue diamond) as well as the uncertainty bars on the estimated intensity value. In many cases, the uncertainty in the estimated emissions is on the order of ±100 percent. Finally, each graph has a line showing the weighted average intensity for the sector (i.e., total emissions for the sector divided by total production for the sector).

199

Gas Plant Emission IntensitiesAll Plants

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0

Cumulative Sales (% of Total)

To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.075

200


0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0

Cumulative Emissions (% of Total)

To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.075

E

201


0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.072

.

202

Gas Plant Emission Emission IntensitiesAll Plants

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.072

203

Gas Plant Emission IntensitiesSweet Plants

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.029

204


0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.029

205


0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.025

206

Gas Plant Emission Emission IntensitiesSweet Plants

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.00 10.00 20.00 30.00 40.00 50.00 60.00 70.00 80.00 90.00 100.00


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.025

207

Gas Plant Emission IntensitiesSour Flaring Plants

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.144

208


0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.144

209


0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.138

210

Gas Plant Emission Emission IntensitiesSour Flaring Plants

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.00 10.00 20.00 30.00 40.00 50.00 60.00 70.00 80.00 90.00 100.00


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.138

211

Gas Plant Emission IntensitiesSour Injection Plants

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.090

212


0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.090

213


0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.087

214

Gas Plant Emission Emission IntensitiesSour Injection Plants

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.087

215

Gas Plant Emission IntensitiesSour Recovery Plants

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.168

216


0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.168

217


0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.167

218


0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Su

m o

f S

ales

(t

CO

2E/m

3 OE

)

Average = 0.167

219

Gas Production Intensities

0.00

0.05

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0

Cumulative Gas Receipts (% of Total)

To

tal E

mis

sio

ns/

Gas

Rec

eip

ts (

t C

O2E

/103 m

3 )

Average = 0.059

220


0.00

0.20

0.40

0.60

0.80

1.00

1.20

1.40

1.60

1.80

2.00

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Gas

Rec

eip

ts (

t C

O2E

/103 m

3 )

Average = 0.059

221


0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0

Cumulative Gas Receipts (% of Total)

Co

vere

d E

mis

sio

ns/

Gas

Rec

eip

ts (

t C

O2E

/103 m

3 )

Average = 0.045

222


0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Gas

Rec

eip

ts (

t C

O2E

/103 m

3 )

Average = 0.045

223

Light/Medium Oil Production Intensities

0.0

0.2

0.4

0.6

0.8

1.0

1.2

1.4

1.6

1.8

2.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0

Cumulative Production (% of Total)

To

tal E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.078

224


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

5.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.078

225


0.0

0.2

0.4

0.6

0.8

1.0

1.2

1.4

1.6

1.8

2.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.048

226


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

5.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.048

227

Heavy Oil/Cold Bitumen Production Intensities

0.0

0.5

1.0

1.5

2.0

2.5

3.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.406

228


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

5.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.406

229


0.0

0.5

1.0

1.5

2.0

2.5

3.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.372

230


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

5.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.372

231

Thermal Production Intensities

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.701

232


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


To

tal E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.701

233


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.699

234


0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0


Co

vere

d E

mis

sio

ns/

Pro

du

ctio

n (

t C

O2E

/m3 O

E)

Average = 0.699

a unified voice for canada's upstream oil and gas industry - a … · 2019-11-26 ·...

Documents