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Respondent CDP 2009: ARC Energy Trust

General introduction


Risk and Opportunities
1 Regulatory Risks (CDP6 1(a)(i))
1 1 company exposed regulatory risks related climate change
We consider our company to be exposed to regulatory risks. 
operations Alberta British Columbia Manitoba Saskatchewan faced potential climate legislation provinces (including involvement regional initiatives Western Climate Initiative) Federal government (see "Further Information" footnote) result ARC faced possibility having manage different emission limits (absolute vs intensity) reporting standards compliance options baseline years International legislation impact medium term (post 2012) result policy developments coming United States international (i e Copenhagen) paying particular attention climate policy developments U S Canadian government indicated intentions align policy U S U S legislation regarding low carbon fuel standards renewable energy requirements directly impact demand products ARC identifies risks numerous ways employees sits industry committee focuses climate policy developments impact upstream oil gas industry Canada (Canadian Association Petroleum Producers (CAPP) Climate Change Working Group) ARC updated quarterly legal counsel auditors proposed changes legislation finally legislative developments tracked ARC Operations group reported quarterly Health & Safety Board Directors sub committee financial impact potential regulatory risks tracked monitored internally potential cost compliance calculated based Federal framework Canadian climate policy Turning Corner released 2008 (although suspect framework altered) Pricing sensitivities (cost carbon) numerous compliance mechanisms (evaluated based accessibility given year) available ARC (i e offsets credits internal abatement etc) evaluated determining overall impact potential climate policy evaluation provides management quantitative ballpark annual cost compliance Canadian climate policy 2018 ARC expects regulatory risks materialize 2012 2015 timeframe views changed past months evolved climate policy developments continue progress gain better understanding facility level data climate related opportunities Specifically based theoretical climate policy compliance model level detail/rigor/assurance foresee required GHG carbon related data focused attention data management internal abatement emission reduction projects

 
information
important note Alberta’ s current climate legislation does directly impact ARC operations impacted indirectly joint venture contracts time cost compliance minimal does present ARC regulatory opportunity addressed question 4 1

 
2 Physical Risks (CDP6 1(a)(ii))
2 1 company exposed physical risks climate change
We do not consider our company to be exposed to physical risks. 
views changed past months time minimal physical risks operations result climate change Threats mountain pine beetle (should spread areas operate possibly impact ability access sites delay development opportunities result beetle related mitigation activities) large temperature variance (impacting timing “ break up” ) forest fires increased storm intensity (resulting increase lightning strikes tornados) expected affect operations significantly short medium term Long term climate change (post 2050) result risks ARC address mainly related facility access (ie quality access roads impacted climate variance) actions taken time address long term issues

 
information

 
3 Risks (CDP6 1(a)(iii))
3 1 company exposed risks result climate change
We consider our company to be exposed to other risks. 
Reputational competitive risks directly linked increase public awareness surrounding climate change people’ s definition “ responsible” business practices Specifically landowners increasingly aware upstream oil gas companies addressing issues climate change environmental issues (land reclamation water management) result reputation line daily basis operations increases need transparency stakeholder communications significant risks business reputation allows maintain competitive advantage marketplace (notably investment community) positions favorable position negotiating landowners risks identified channels mentioned 1 1 plus identified research Corporate Responsibility report released December 2008 report path greater transparency issues impact operations relationship stakeholders plan use Corporate Responsibility report means develop corporate carbon (or climate) strategy tracking reporting non financial performance availability document internal external stakeholders promote greater sense corporate accountability metrics reporting document ARC identified financial risks associated climate change include regulatory compliance costs (addressed 1 1 includes potential increasing cost declining access offsets/credits) capital expenditures associated mitigation adaptation activities (i e investment carbon capture & storage GHG/CO2 reduction projects requiring capital outlay) potential increase cost energy (i e electricity) risk surrounding access investment capital (i e investor awareness climate related management “ socially responsible investment” ) ARC begun explore pursue options help company manage financial risks mentioned 1 1 ARC developed regulatory compliance cost model includes increasing cost carbon (via technology fund payments) increasing cost purchase offsets create credits analysis ARC’ s 30+ highest emitting facilities encompasses years 2010 2018 noted CDP6 ARC committed significant capital research development enhanced oil recovery (EOR) projects lead carbon sequestration Late 2005 ARC intentionally acquired oil reservoirs believe prime candidates EOR carbon storage injection carbon dioxide Pending infrastructure developments carbon capture expect able sequester large amounts carbon reservoirs increase ultimate oil recovery CO2 EOR project Redwater proved economically viable able sequester 5 000 15 000 tonnes CO2 day company committed budget energy efficiency projects (ARC’ s Eco Efficiency Initiative (EEI)) budget exclusively aims support develop projects achieve significant reductions fuel electricity consumption greenhouse gas reductions initiative developed 2008 began implementation Q1 2009

 
information

 
4 Regulatory Opportunities (CDP6 1(b)(i))
4 1 regulatory requirements climate change present opportunities company
Regulatory requirements present opportunities for my company. 
Regulatory requirements (real potential) presented ARC opportunities provided incentive improve tracking management facility level greenhouse gas energy related data resulted implementation data management software program improve mandatory voluntary GHG energy reporting promoted greater awareness climate risks facing company specifically highest risk facilities related GHG regulatory compliance Climate related policy prompted government investment carbon capture & storage Alberta Canadian governments committed funds research development technology ARC able capitalize securing funds funds support ARC’ s ongoing developing EOR pilot projects help fund ongoing research CCS projects Redwater Wabamum areas projects provide financial benefits company (via enhanced recovery) environmental benefits province country position ARC favourably event amenable carbon trading scheme developed coming years

 
information

 
5 Physical Opportunities (CDP6 1(b)(ii))
5 1 physical changes resulting climate change present opportunities company
Physical changes do not present opportunities for my company. 
industry operates temperature variances environments result ARC does foresee opportunities physical change time increase extreme weather continue impacts infrastructure relevant industry (notably refineries southern United States) view physical opportunity

 
information

 
6 Opportunities (CDP6 1(b)(iii))
6 1 Does climate change present opportunities company
Climate change presents other opportunities for my company. 
Climate change awareness regulations presents ARC opportunity communicate promote core commitment environment “ doing what’ s right just what’ s required” favourable report card relates sound business operations concerted environmental management care stakeholder concerns increase climate related reporting requirements increase public awareness environmentally responsible business operations provided ARC opportunity communicate successes discuss plan action address shortcomings

 
information

 
Greenhouse Gas (GHG) Emissions Accounting, Emissions Intensity, Energy and Trading
7 Reporting Year (CDP6 Q2(a)(ii))
Information respond section “ Greenhouse Gas Protocol Corporate Accounting Reporting Standard (Revised Edition)” developed World Resources Institute World Business Council Sustainable Development (“ GHG Protocol” ) http //www ghgprotocol org/ ISO 14064 1 compatible GHG Protocol number regional/national programme protocols information http //www ghgprotocol org/ use guidance button provide CDP responses questions 7 8 9 10 1 10 2 11 1 11 2 years prior current reporting year time answered CDP information request work backwards current reporting year enter data oldest reporting period Questions 10 1 10 2 11 1 11 2 subsequent webpages dates answer question 7 carried forwards automatically populate webpages
7 1 state start date end date year reporting GHG emissions
Start date 01 January 2007End date 31 December 2007Financial accounting year 01 January 2007

 
8 Reporting Boundary (CDP6 Q2(a)(i)) 8 1 indicate category describes company entities group Scope 1 Scope 2 GHG emissions reported
Companies over which financial control is exercised – per consolidated audited Financial Statements. 

 
8 2 state parts business sources GHG emissions excluded reporting boundary
Non operated equity share GHG emissions excluded reporting boundary

 
9 Methodology (CDP6 Q2(a)(iii)) 9 1 process used company calculate Scope 1 Scope 2 GHG emissions including standard protocol methodology used collect activity data calculate Scope 1 Scope 2 GHG emissions provide answer text box addition description relevant select methodology list published methodologies aid automated analysis data
process data collection analysis estimating totals reductions emissions energy use follows guidelines published Canadian Association Petroleum Producers (CAPP) independent consulting firm performed calculations following details en excerpt description collection calculation methodology “ Data ARC Resources’ operated batteries gas gathering systems areas covering B C Alberta Saskatchewan Manitoba included analysis Emissions energy use contractors fleet vehicles head office included analysis Data oil gas production fuel gas flare gas collected production reports report production refers production sales includes deliveries ARC operated gas plants gas gathering systems batteries party Purchased fuel gas recorded production reports sources fuel purchased propane accounted calculations Electricity data obtained electric utilities used determine quantity electric power used various sites GHG emissions generated electric utilities source indirect emissions ARC emissions included report direct emissions data analysis includes following • Emission associated use electric energy• Fuel gas emissions gas engines heaters boilers• Flaring emissions• Fugitive emissions methane losses Emissions resulting combustion calculated combustion equipment data determine correct emission factor fuel gas use piece combustion equipment engine greater 130HP heater/boiler rating greater 1MMBTU Fugitive emissions estimated using fugitive emission factors provided CAPP ‘ Short Form’ method light oil fugitive emission factor applied light oil deliveries batteries account fugitive emission oil production wellhead battery natural gas production fugitive emission factors provided CAPP ‘ Short Form’ gas plant fugitive emissions factors applied gas plant sales estimate total fugitive emissions gas production wellhead gas plant ” method allows emissions calculated GHG type carbon dioxide (CO2) methane (CH4) nitrous oxide (N2O)

 
Select methodologies
Canadian Association of Petroleum Producers (CAPP), "Calculating Greenhouse Gas Emissions", April 2003


 
provide

 
9 2 Details assumptions
exception combustion equipment data noted 9 1 assumptions utilization rates load factors applying industry factors CAPP’ s “ Calculating Greenhouse Gas Emissions” Guide equipment specifications accordance equipment manual cases fuel gas attributed specifically piece equipment assumption engines consumed 25% 100% fuel gas batteries gas gathering systems respectively rest fuel gas deemed consumed burners heaters boilers assumptions accordance CAPP’ s “ Calculating Greenhouse Gas Emissions” Guide including calculation vented emissions

 
9 3 names links calculation tools used
calculation tools refer CAPP’ s “ Calculating Greenhouse Gas Emissions” Guide April 2003 http //membernet capp ca/default asp V_DOC_ID=1007& PubID=55904 ARC’ s 2008 submission Canadian Standard’ s Association GHG Challenge Registry http //www ghgregistries ca

 
Select calculation tools
CAPP’s “Calculating Greenhouse Gas Emissions” Guide, April 2003. http://membernet.capp.ca/default.asp?V_DOC_ID=1007&PubID=55904


 
9 4 global warming potentials applied origin
calculation tools refer CAPP’ s “ Calculating Greenhouse Gas Emissions” Guide April 2003 http //membernet capp ca/default asp V_DOC_ID=1007& PubID=55904 CO2 1CH4 21N2O 310

 
9 5 emission factors applied origin
calculation tools refer CAPP’ s “ Calculating Greenhouse Gas Emissions” Guide April 2003 http //membernet capp ca/default asp V_DOC_ID=1007& PubID=55904 ARC’ s 2008 submission Canadian Standard’ s Association GHG Challenge Registry http //www ghgregistries ca Emission factors likely change 2008 data Environment Canada updated emission factors associated provincial electricity consumption expect changes future GHG calculations associated electricity Scope 2 emissions

 
information

 
10 Scope 1 Direct GHG Emissions (CDP6 Q2(b)(i))
Instructions question 10 question 11 (following page)When providing answers questions 10 11 deduct offset credits Renewable Energy Certificates net estimated avoided emissions export renewable energy carbon sequestration (including enhanced oil recovery) use goods services Opportunities provide details activities reduce avoid emissions provided information request Carbon dioxide emissions biologically sequestered carbon e g carbon dioxide burning biomass/biofuels reported separately emissions Scopes 1 2 3 relevant report emissions question 15 include nitrous oxide methane emissions biomass/biofuel combustion emissions scopes
answer following questions using Table 1 provide 10 1 Total gross global Scope 1 GHG emissions metric tonnes CO2 ePlease break total gross global Scope 1 emissions 10 2 Country regionPlease provide CDP responses questions 10 1 10 2 years prior current reporting year time answered CDP information request work backwards current reporting year enter data oldest reporting period Table 1 (below) table 5 (Q11 1 11 2) automatically populated dates answer 7 1 Electric utilities report emissions country/region using table question EU3 Table 1 use numbers Use “ Other” option drop menu enter region
Reporting year Q7.1 Start date 01/01/2007
Reporting year Q7.1 End date 31/12/2007
10.1 Total gross global Scope 1 GHG
emissions in metric tonnes CO2-e
359742

10.2 Gross Scope 1 emissions in metric tonnes CO2-e by country or region


 
answer question 10 1 automatically carried forward tables 2 3 add country region answer 10 2 press “ Save” end page tick box total gross global Scope 1 figure (Q10 1) includes emissions transferred outside reporting boundary (as given answer 8 1) report transfers 13 5

 
facilitate better understanding business break total global Scope 1 emissions 10 3 Business divisionand/or10 4 Facility10 3 Business division (only data current reporting year requested)Table 2 use numbers
Business Divisions - Enter names below
Scope 1 Metric tonnes CO2-e
Total gross global Scope 1 GHG emissions in metric tonnes CO2-e - answer to question Q10.1 359742

 
10 4 Facility (only data current reporting year requested)Table 3 use numbers
Facilities - Enter names below
Scope 1 Metric tonnes CO2-e
Total gross global Scope 1 GHG emissions in metric tonnes CO2-e - answer to question Q10.1 359742
Gas Plants 73645
Gas Gathering Systems 64305
Batteries 221793

 
10 5 break total global Scope 1 GHG emissions metric tonnes gas metric tonnes CO2 e GHG type (Only data current reporting year requested )Table 4 use numbers
Scope 1 GHG Type
Unit
Quantity
CO2 Metric tonnes 240961
CH4 Metric tonnes 4918
CH4 Metric tonnes CO2-e 103281
N2O Metric tonnes 50
N2O Metric tonnes CO2-e 15500
HFCs Metric tonnes
HFCs Metric tonnes CO2-e
PFCs Metric tonnes
PFCs Metric tonnes CO2-e
SF6 Metric tonnes
SF6 Metric tonnes CO2-e

 
10 6 provided information Scope 1 emissions response questions explain reasons plans collecting Scope 1 GHG emissions information future

 
information

 
11 Scope 2 Indirect GHG Emissions (CDP6 Q2(b)(i))
Important note emission factors zero low carbon electricity purchased emissions factor use calculating Scope 2 emissions depends electricity purchase counted calculating grid average emissions factor – supplier Electricity counted calculating grid average emissions factor electricity sourced grid electricity counted calculating grid average emissions factor Scope 2 emissions calculated using grid average emissions factor company purchases electricity zero low carbon electricity tariff Electricity counted calculating grid average emissions factor zero low carbon electricity sourced grid transmitted company electricity counted calculating grid average emissions factor specific method generation used provided certificates quantifying GHG related environmental benefits claimed electricity sold passed separately electricity purchased Click instructions previous page answering question 11
answer following questions using Table 5 provide 11 1 Total gross global Scope 2 GHG emissions metric tonnes CO2 e break total gross global Scope 2 emissions 11 2 Country regionPlease provide CDP responses questions 11 1 11 2 years prior current reporting year time answered CDP information request work backwards current reporting year enter data oldest reporting period Table 5 automatically populated dates gave answer 7 1 Table 5 use numbers Use “ Other” option drop menu enter region
Reporting year Q7.1 Start date 01/01/2007
Reporting year Q7.1 End date 31/12/2007
11.1 Total gross global Scope 2 GHG
emissions in metric tonnes CO2-e
356166

11.2 Gross Scope 2 emissions in metric tonnes CO2-e by country or region


 
answer 11 1 automatically carried forward tables 6 7 add country region answer 11 2 press “ Save” end page facilitate better understanding business break total global Scope 2 emissions 11 3 Business divisionand/or11 4 Facility11 3 Business division (only data current reporting year requested)Table 6 use numbers
Business Divisions - Enter names below
Scope 2 Metric tonnes CO2-e
Total gross global Scope 2 GHG emissions in metric tonnes CO2-e - answer to question Q11.1 356166
Canada 356166
Alberta 300468
Saskatchewan 55321
British Columbia 333
Manitoba 44

 
11 4 Facility (only data current reporting year requested)Table 7 use numbers
Facilities - Enter names below
Scope 2 Metric tonnes CO2-e
Total gross global Scope 2 GHG emissions in metric tonnes CO2-e - answer to question Q11.1 356166

 
11 5 provided information Scope 2 emissions response questions explain reasons plans collecting Scope 2 GHG emissions information future
feasible determine facility level Scope 2 emissions

 
information

 
12 Contractual Arrangements Supporting Particular Types Electricity Generation (CDP6 Q2(b)(i) Guidance)
12 1 consider grid average factor used report Scope 2 emissions question 11 does reflect contractual arrangements electricity suppliers (for example purchase electricity using zero low carbon electricity tariff) calculate report contractual Scope 2 figure response question showing origin alternative emission factor information tariff
applicable

 
12 2 retire certificates (eg Renewable Energy Certificates) associated zero low carbon electricity provide details
applicable

 
information

 
13 Scope 3 Indirect GHG Emissions (CDP6 Q2(c))
following categories main sources emissions Report emissions metric tonnes CO2 e state methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions Notes question 13When providing answers question 13 deduct offset credits Renewable Energy Certificates net estimated avoided emissions export renewable energy carbon sequestration (including enhanced oil recovery) use goods services Opportunities provide details activities reduce avoid emissions provided information request Carbon dioxide emissions biologically sequestered carbon e g carbon dioxide burning biomass/biofuels reported separately emissions Scopes 1 2 3 relevant report emissions question 15 include nitrous oxide methane emissions biomass/biofuel combustion emissions scopes
13 1 Employee business travelDescribe main sources emissions
currently track Scope 3 emissions main sources employee business travel emissions air travel employee commuting vehicles owned controlled organization employee air travel involves short haul flights long haul flights North America Europe place Emissions contractor owned vehicles difficult track reasonable time

 
Emissions metric tonnes CO2 e

 
State methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions

 
13 2 External distribution/logisticsDescribe main sources emissions

 
Emissions metric tonnes CO2 e

 
State methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions

 
13 3 Use/disposal company’ s products servicesFor auto manufacture auto component companies – refer additional questions sectors completing question 13 3 main sources emissions

 
Emissions metric tonnes CO2 e

 
State methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions

 
13 4 Company supply chainDescribe main sources emissions

 
Emissions metric tonnes CO2 e

 
State methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions

 
13 5 OtherIf reporting emissions fall categories categorise transferred emissions non transferred emissions (please guidance explanation terms) report transfers input fields non transfers input fields TransfersDescribe main sources emissions

 
TransfersReport emissions metric tonnes CO2 e

 
TransfersState methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions

 
Non transfersDescribe main sources emissions

 
Non transfersReport emissions metric tonnes CO2 e

 
Non transfersState methodology assumptions calculation tools databases emission factors (including sources) global warming potentials (including sources) used calculating emissions

 
13 6 provided information categories Scope 3 GHG emissions response questions explain reasons plans collecting Scope 3 indirect emissions information future
tremendous logistical administrative complexities involved calculating tracking Scope 3 emissions internal mechanism tracking air travel example conducive reliable data collection currently exploring ways improve mechanism Employee commuting contractor vehicle travel extremely difficult track reliability ARC employees provinces individual travels different distance Contractors work numerous companies given time travel sites owned different companies Calculating travel time/distance associated company extremely difficult time consuming Calculating external distribution products reasonable entail double counting emissions reported “ mid stream” transportation companies industry product reaches distribution point combined products companies determining emissions associated specifically ARC products reasonable

 
information

 
14 Emissions Avoided Use Goods Services (New CDP 2009)
14 1 goods and/or services enable GHG emissions avoided party provide details including estimated avoided emissions anticipated timescale emissions avoided methodology assumptions emission factors (including sources) global warming potentials (including sources) used estimations
applicable

 
information

 
15 Carbon Dioxide Emissions Biologically Sequestered Carbon (New CDP 2009)
example carbon dioxide burning biomass/biofuels

 
15 1 provide total global carbon dioxide emissions metric tonnes CO2 biologically sequestered carbon Emissions metric tonnes CO2 use numbers

 
information
applicable

 
16 Emissions Intensity (CDP6 Q3(b))
16 1 supply financial emissions intensity measurement reporting year combined Scope 1 2 emissions measurement
EBITDA (USD)

 
16 1 1 units example units metric tonnes CO2 e million Yen turnover metric tonnes CO2 e US$ profit metric tonnes CO2 e thousand Euros turnover
tonnes CO2e / USD EBITDA

 
16 1 2 resulting figure Use decimal point necessary use “ ” “ ” e write 15 6 15 6
0.00106

 
16 2 supply activity related intensity measurement reporting year combined Scope 1 2 emissions measurement
tonnes CO2e cubic meter oil equivalent (m3OE) cubic meter oil equivalent standard measure productin upstream oil gas industry normalizes production petroleum products common unit

 
16 2 1 units e g metric tonnes CO2 e metric tonne output service sector businesses unit service provided
tonnes CO2e / m3OE

 
16 2 2 resulting figure Use decimal point necessary use “ ” “ ” e write 15 6 15 6
0.197

 
information

 
17 Emissions History (CDP6 Q2(f))
17 1 emissions reporting year vary significantly compared previous years
No - Please go to question 18. 

 
answer 17 1 Yes 17 1 1 Estimate percentage emissions vary compared previous reporting year box accept numerical answers containing decimal point use " " " " e write 10 6 10 6

 
emissions increased decreased

 
information

 
18 External Verification/Assurance (CDP6 Q2(d))
18 1 information reported response questions 10 – 15 externally verified/assured
None of the information provided in response to question 10-15 has been externally verified/assured in whole or in part. Please go to question 18.6. 

 
aid automated analysis responses select responses tick boxes use text box provided tick boxes menu options appropriate

 
18 2 State scope/boundary emissions included verification/assurance exercise

 
use text box scope/boundary emissions included verification/assurance exercise tick box menu options applicable

 
18 3 State level assurance (eg reasonable limited) given

 
18 4 Provide copy verification/assurance statement attach copy/copies

 
18 5 Specify standard information verified/assured

 
18 6 information provided response questions 10 15 verified state plans GHG emissions accounting information externally verified/assured future
currently process implementing data management software improve tracking GHG emissions related data internal “ housekeeping” measures data management standpoint exploring external verification/assurance updated systems place point comfortable moving forward measures

 
information

 
19 Data Accuracy (CDP6 Q2(e) – New wording CDP 2009)
19 1 main sources uncertainty data gathering handling calculations e g data gaps assumptions extrapolation metering/measurement inaccuracies gather emissions data select emissions data gathered proceed question 20
Emission data is gathered. 
main sources uncertainty data gathering handling calculations surround measurement vented gas fugitive emissions electricity consumption (allocation) Given difficulty collect vent volumes numbers estimated inlet volumes product equipment specs applies fugitive emissions noted CAPP mandated member companies implement year fugitive emissions program measure fugitive volumes selected facilities ultimately help companies determine common sources corporate electricity consumption number known facility level consumption discrepancy does impact corporate emissions calculations does impact ability measure Scope 2 emissions facility level data uncertainty arising use party calculate emissions likely result employee turnover consultancy Historically minor gaps relating data gathering facilities outside Alberta result fact British Columbia Saskatchewan Manitoba data difficult track Alberta data currently central registry provinces Alberta (The Petroleum Registry) Plus Alberta stringent regulations surrounding collection certain data points (i e flare volumes) result possible emission related data points like flare volumes captured outside Alberta

 
19 2 uncertainties affect accuracy reported data percentage terms estimated standard deviation
Unknown

 
19 3 Does company report GHG emissions mandatory voluntary scheme (other CDP) requires accuracy assessment
No (Please go to question 20.) 

 
19 3 1 provide scheme

 
19 3 2 provide accuracy assessment GHG emissions reported scheme report delivered

 
information

 
20 Energy Fuel Requirements Costs (New CDP 2009)
provide following information reporting year Cost purchased energy
20 1 total cost electricity heat steam cooling purchased company
31558673

 
Select currency
Canadian dollar

 
20 1 1 break costs individual energy type Table 8 “ Cost” column accept text use numbers
Energy type
Cost
Currency
 Electricity 31558673 Canadian dollar
 Heat Canadian dollar
 Steam Canadian dollar
 Cooling Canadian dollar

 
Cost purchased fuel20 2 total cost fuel purchased company mobile stationary combustion
3683660

 
Select currency
Canadian dollar

 
20 2 1 breakdown costs individual fuel type Table 9 cost column accept text use numbers
Mobile combustion fuels
Cost
Currency
Gasoline / petrol 1194935 Canadian dollar

 
Stationary combustion fuels
Cost
Currency
Natural gas 2488725 Canadian dollar

 
Energy fuel inputsThe following questions designed establish company’ s requirements energy fuel (inputs) note MWh preferred unit answers helps comparability analysis usually associated electricity equally used represent energy content fuels (see CDP2009 Reporting Guidance information conversions MWh) Purchased energy input20 3 company’ s total consumption purchased energy MWh use numbers
456046 MWh

 
Purchased self produced fuel input20 4 company’ s total consumption MWh fuels stationary combustion includes purchased fuels biomass self produced fuels relevant use numbers
1147657 MWh

 
answering question used Higher Heating Values (also known Gross Calorific Values) Lower Heating Values (also known Net Calorific Values) state used calculating answers
Higher Heating values

 
20 4 1 break total consumption fuels reported answer question 20 4 individual fuel type MWh Table 10 use numbers
Stationary combustion fuels
MWh
Natural gas 1147657

 
Energy outputIn question ask information energy MWh generated company fuel uses Comparing energy contained fuel combustion (question 20 4) energy available use combustion indication efficiency combustion processes taking industry sector account 20 5 total energy generated MWh fuels reported question 20 4 use numbers
0 MWh

 
20 6 total MWh renewable energy excluding biomass self generated company use numbers
0 MWh

 
Energy exportsThis question companies export energy surplus requirements example company use electricity combined heat power plant export heat organisation 20 7 percentage energy reported response question 20 5 exported/sold company grid parties use numbers
0 %

 
20 8 percentage renewable energy reported response question 20 6 exported/sold company grid parties use numbers
0 %

 
information

 
21 EU Emissions Trading Scheme (CDP6 Q2(g)(i) – New wording CDP 2009)
Electric utilities report allowances emissions using table question EU5 21 1 Does company operate ownership facilities covered EU Emissions Trading Scheme (EU ETS)
No (Please go to question 22.) 

 
details 21 2 allowances allocated free year Phase II facilities operate (Even wholly facilities number allowances) Table 11 use numbers
2008
2009
2010
2011
2012
Free allowances metric tonnes CO2

 
21 3 total allowances purchased national auctioning processes period 1 January 2008 31 December 2008 facilities operate (Even wholly facilities total allowances purchased auctions facilities period) Total allowances purchased auction

 
21 4 total CO2 emissions 1 January 2008 31 December 2008 facilities operate (Even wholly facilities total emissions period )Total emissions metric tonnes

 
information

 
22 Emissions Trading (CDP6 Q2(g)(ii) New wording CDP 2009)
Electric utilities read EU6 answering questions
22 1 provide details emissions trading schemes EU ETS company participates likely participate years
We participate or anticipate participating in trading schemes other than the EU ETS in the next two years. 
actively exploring avenues participant Alberta’ s emission trading joint venture obligations large final emitter (LFE) facilities regulated Alberta’ s Specified Gas Emitters Regulation opportunity achieve compliance portion requirement monetary contribution tech fund purchasing offsets light estimation facility level regulatory threshold decrease time (from 100 kT 50 kT low 25 kT) expecting ARC’ s compliance requirements increase short medium term exploring opportunities exist participate offset market Participation Alberta offset market provide valuable experience if/when Federal comes play

 
22 2 overall strategy complying schemes required elected participate including EU ETS
ARC’ s strategy includes exploring offset credit generation “ Eco Efficiency Initiative” (EEI) credit generation EOR projects EEI launched Q1 2009 budget dedicated promoting supporting efficiency projects meet standard economic hurdles result significant environmental benefits Specifically initiative focuses supporting projects achieve fuel use reductions energy efficiency measures outside normal business practices initiative prove successful (i e achieve measurable results) ARC explore possibility applying credits Alberta mentioned 22 1 plan explore purchasing offsets Alberta market ARC’ s strategy compliance Federal scheme currently focused determining cap trade impact operations focus enhanced oil recovery carbon capture storage Redwater (and Pembina) areas remains important piece GHG strategy medium long term mentioned ARC’ s CDP6 submission (Q1(a)(iv) Q1(b)(iv)) “ ARC intentionally acquired oil reservoirs believe prime candidates enhanced oil recovery carbon storage injection carbon dioxide infrastructure carbon capture available expect able sequester large amounts carbon reservoirs increase ultimate oil recovery Depending happens carbon trading mechanisms Canada end significant carbon credits just CO2 EOR project Redwater proved commercial able sequester 5 000 15 000 tonnes CO2 day allow major player carbon trading ”

 
information

 
22 Carbon credits
22 3 purchased project based carbon credits
No. (Please go to question 22.5) 

 
indicate credits meet following commitments

 
22 4 Provide details including type unit volume vintage purchased standard/scheme credits verified issued retired (where applicable)

 
22 5 involved origination project based carbon credits
Yes. (Please answer the following question) 

 
22 6 provide details including • role project(s) • locations technologies involved • standard/scheme projects being/have developed • emissions reductions validated verified • annual volumes generated/projected carbon credits • Retirement method used compliance offsetting
BlueSource Canada ARC completed Notification Federal Government’ s Turning Corner Credit Early Action Program July 2008 Phase application required extensive analysis data relating GHG reductions result project applied (the construction gas plant Lougheed SK) project required installation equipment including refrigeration unit natural gas sweetening unit incinerator units existed site previously recovery processing solution gas undertaken previously solution gas flared project activity required new equipment ARC required regulatory body implement project came high capital costs long payback period compared industry standard Annual GHG reductions 5 987 tonnes CO2 equivalent calculated validated/verified party

 
22 7 involved trading allowances EU ETS and/or project based carbon credits separate business activity direct support business activity investment fund management provision offsetting services
No. (Please go to question 23) 

 
22 8 provide details role performed

 
information

 
Performance
23 Reduction plans & goals (CDP6 Q3(a))
23 1 Does company GHG emissions and/or energy reduction plan place
Yes. (Please go to question 23.3) 

 
23 2 explain aid automated analysis responses select response options using text box just use text box provided options appropriate

 
menu options appropriate answer question using text box

 
Goal setting23 3 emissions and/or energy reduction target(s)
Yes. (Please answer the following questions) 

 
23 4 baseline year target(s)
Currently ARC modeling reduction targets 2006 baseline noted rolling baseline (each year baseline previous year) prove effective baseline given nature upstream oil gas industry (declining basin growth (replacing reserves) acquisitions divestitures etc)

 
23 5 emissions and/or energy reduction target(s)
Eco Efficiency Initiative plans implement targets beginning 2010 running 2012 program evaluated annual basis longevity largely depend Canadian climate policy post 2012 meantime ARC set 2009 greenhouse gas emissions target expect reduce total GHG emissions 3 4% 2008 levels amounts absolute reduction 20 000 28 000 tonnes CO2e

 
23 6 sources activities target(s) applies
operations Reductions fuel use (primarily combustion equipment includes flare vent volumes) electricity consumption main areas focus terms means achieving GHG target (impacting Scope 1 Scope 2 emissions) geological locations considered

 
23 7 period/timescale does target(s) extend
current target applies 2009 emissions 2010 2012 targets forthcoming

 
information

 
23 GHG emissions energy reduction activities
23 8 activities undertaking planning undertake reduce emissions/energy use
pursuing variety reduction initiatives pursuing renewable energy alternatives power generation including solar powered generators chemical injection pumps site wind power generation exploring installation high efficiency burners (on treators example) tying production wells reduce flaring volumes (a significant project expected complete summer 2009) installing generation units reduce fuel electricity consumption modifications dehydrator units (associated operating parameters) reduce benzene emissions incorporated fugitive emissions monitoring program order reduce vented emissions Construction CO2 EOR pilot project Redwater oil field complete injection commenced summer 2008 expect inject 60 kilotonnes (kt) CO2 life project help ARC determine commercial viability EOR CO2 injection field commercial EOR project potential inject 10 15 kt CO2 day (50 million tonnes life project) addition participating carbon sequestration pilot project water bearing portion Redwater Leduc reef (known HARP initiative – Heartland Area Redwater Project) pure sequestration Redwater Leduc water bearing reef complex viable believe reef hold 1 000 megatonnes (Mt) CO2 evaluating CO2 EOR pilot project Pembina district completed reservoir modeling preparation detailed design pilot implementation 2009/2010 Eco Efficiency Initiative referenced 22 2 drive reduction initiatives listed used means improve emission data management project evaluation initiative set field operators submit efficiency project ideas operators mandated fuel use electricity emissions target expecting variety projects submitted year

 
information

 
23 Goal evaluation
23 9 benchmarks key performance indicators use assess progress emissions/energy reduction goals set
metrics included Eco Efficiency Initiative include • Absolute tonnes CO2e reduced • Production Carbon Intensity (tonnes CO2e/m3 oil equivalent) • $ spent tonne CO2e reduced

 
information

 
23 Goal achievement
23 10 emissions reductions energy savings associated cost savings achieved date result plan and/or activities described state methodology data sources used calculating reductions savings
Redwater pilot project CO2 injected date 5 300 tonnes (direct measurement based injection rates)We expecting Eco Efficiency Initiative achieve CO2e reductions 15 25 kilotonnes 2009 (based scheduled flare reductions approved projects) noted submission CDP6 “ result previous emission reduction plan reduced absolute emissions 204 796 tonnes CO2e cumulative basis (’ 99 ’ 06) ” did capture reduction initiatives 2007 result factors including pace development industry 2007 regulatory uncertainty surrounding Canadian climate policy (including carbon markets) elected step evaluate risks associated potential climate policy evaluating internal data management systems evaluation entailed scenario planning different policy requirements compliance costs culminated Eco Efficiency Initiative

 
23 11 investment required achieve emissions reductions energy savings targets carry activities listed response question 23 8 period investment Table 13 “ Investment number” column accept text use numbers
Emission reduction target/energy saving target or activity
Investment number
Investment currency
Timescale
Phase 1 Hearthland Area Redwater Project 1200000 Canadian dollar 2008 2009
Eco Efficiency Initiative 1000000 Canadian dollar 2009

 
information
EOR pilot project Redwater estimated cost $30 $35 million (between 2008 2010) field CO2 EOR capital cost estimated $600 $800 million life operating costs $1 billion capital costs associated EOR pilot project Pembina estimated $20 $25 million (between 2009 2013) estimates include potential cost acquiring CO2 reduction initiatives listed 23 8 (aside EOR CCS projects) expected funded Eco Efficiency Initiative 2010 Eco Efficiency budget set fall 2009

 
23 Goal planning & investment
Electric utilities read table question EU3 giving details forecasted emissions
23 12 investment required achieve future targets set reduction plan carry activities listed response question 23 8 period expect payback investment Table 14 “ Number” column accept text use numbers
Plan or action
Investment number
Investment currency
Payback

 
23 13 estimate company’ s future Scope 1 Scope 2 emissions years main territories regions operate provide qualitative explanation expected changes impact future GHG emissions possible use table 15 structure answer question alternatively use text box
Scope 1 Scope 2 emissions expected increase 2010 significantly 2011 2012 result production growth primarily associated construction gas processing facility northeast British Columbia NB figures include emission reductions achieved Eco Efficiency Initiative related projects (including CO2 credits result Redwater Pembina EOR projects)

 
Scope 1 forecasted emissions Table 15 following units
tonne CO2e

 
Scope 2 forecasted emissions Table 15 following units
tonnes CO2e

 
Table 15 “ Scope” columns accept text use numbers Type territory region giving data press “ Add Territory/Region” giving global figure instead separate figures regions territories write “ global” box labelled “ Enter territory region” Click sample table
Future reporting years:
End date for year end DD/MM/YYYY 31/12/2008 31/12/2009 31/12/2010 31/12/2011 31/12/2012
Emission forecasts
Scope 1
Scope 2
Scope 1
Scope 2
Scope 1
Scope 2
Scope 1
Scope 2
Scope 1
Scope 2
Canada 365884 358837 344052 361528 415686 364239 521839 366971 607230 369723

 
23 14 estimate company’ s future energy use years main territories regions operate provide qualitative explanation expected changes impact future GHG emissions possible use table 16 structure answer question alternatively use text box
EEI pursuing energy use targets 2010 2012 period feel appropriate metrics drive corporate GHG reductions (i e 5% fuel use reduction 201X) meantime energy use targets set mentioned 23 13 expect energy use emissions profile increase 2010 2012 result Dawson gas plant coming line

 
Table 16 use numbers Type territory region giving data description data giving e g electricity consumption press “ Add Row” giving global figure instead separate figures regions territories use word “ global” table accept different types units e g units volume mass Click sample table
Future reporting years:
End date for year end DD/MM/YYYY
Energy use estimates for territory/region
Number
Units
Number
Units
Number
Units
Number
Units
Number
Units

 
23 15 explain methodology used estimations assumptions
targets best estimates expect evolve year year especially given recent implementation EEI (a commitment pursuit emission reduction projects) nature business (driven numerous factors including commodity prices capital costs regulatory changes acquisitions & divestitures production growth capital development ) difficult commit long term greenhouse gas targets (3 years + reporting year) Furthermore target setting challenge fact resources naturally depleting time (about 2% year) consequently require energy extract marginal unit resource planning follows 5 year time frame spite challenges understanding targets prove unrealistic emissions sources (Scope 1 Scope 2 emissions) follow definition laid GHG Protocol data collection process methods estimating totals reductions emissions energy use follow guidelines published Canadian Association Petroleum Producers (CAPP)

 
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23 12 Given Eco Efficiency Initiative just recently launched investment requirements known time sophisticated targets concrete expect able better track associated investment requirements Payback project EEI vary Refer question 23 11 investment requirements associated EOR CCS projects

 
24 Planning (CDP6 Q3(c))
24 1 factor cost future emissions capital expenditures impact estimated costs investment decisions
recently begun factor cost future emissions capital expenditure planning example design Dawson gas plant constructing northeast British Columbia considered equipment options based emissions levels (i e gas vs electric powered turbines) future emission related regulatory compliance requirements (i e install Continuous Emissions Monitoring Systems) Plus designated $1 million past years fund capital development projects directly reduce emissions program formalized 2009 “ Eco Efficiency Initiative” previously discussed submission noted 22 2 acquisition Redwater Pembina properties late 2005 potential store volumes CO2 result potential enhanced oil recovery carbon sequestration projects consideration future emissions

 
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Governance
25 Responsibility (CDP6 Q4(a))
25 1 Does Board Committee executive body overall responsibility climate change
Yes. (Please answer question 25.3 and 25.4) 

 
25 2 state overall responsibility climate change managed indicate highest level company responsibility climate change

 
25 3 Board Committee executive body overall responsibility climate change
Health Safety Environment (HSE) Committee

 
25 4 mechanism Board executive body reviews company’ s progress status regarding climate change
HSE Committee meets quarterly review discuss company’ s progress status regarding climate change information presented Vice President Operations Manager Health Safety Environment

 
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26 Individual Performance (CDP6 Q4(b))
26 1 provide incentives individual management climate change issues including attainment GHG targets
No. (Please go to question 27.1) 

 
26 2 incentives linked monetary rewards

 
26 3 entitled benefit incentives

 
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27 Communications (CDP6 Q4(c))
27 1 publish information risks opportunities presented company climate change details emissions plans reduce emissions
Yes

 
indicate following apply provide details and/or link documents copy relevant excerpt 27 2 company’ s Annual Report mainstream filings
Yes 
Climate change regulations related issues addressed Quarterly Annual Management’ s Discussion & Analysis (MD& A) website copy Annual Quarterly reports (www arcresources com) Excerpt 2007 Annual Report (p 53)CLIMATE CHANGE PROGRAMS March 8 2007 Alberta government introduced legislation reduce greenhouse gas emission intensity 3 states facilities emitting 100 000 tonnes greenhouse gases year reduce emissions intensity 12 cent average emissions levels 2003 2004 2005 able facilities required pay $15 tonne tonneabove 12 cent target effective July 1 2007 time Trust determined impact legislation minimal based ARC’ s existing facilities ownership April 2007 Federal Government announced new climate change plan calls greenhouse gas emissions reduced 20 cent current levels 2020 Firms employ following strategies achieve targets able • make house reductions • advantage domestic emissions trading • purchase offsets • use Clean Development Mechanism Kyoto Protocol • invest technology fund Trust waiting additional information fully assess impact new legislation operations January 24 2008 Alberta Government announced plan reduce projected emissions province 50 cent new climate change plan 2050 result real reductions 14 cent 2005 levels Alberta Governmentstated form government industry council determine forward plan implementing technologies significantly reduce greenhouse gas emissions capturing air emissions industrial sources locking permanently underground deep rock formations addition plan calls energy conservation individuals increased investment clean energy technologies incentives expanding use renewable alternative energy sources bioenergy wind solar power hydrogen geothermal energy Initiatives theme account 18 cent Alberta’ s reductions detailed implementation plan developed released spring 2008

 
27 3 Voluntary communications (other CDP) Corporate Social Responsibility reporting
Yes 
Corporate Responsibility Report report issued December 2008 website (www arcresources com) report communicates historic emissions risks opportunities presented ARC climate change regulations states objectives moving forward

 
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28 Public Policy (CDP6 Q4(d))
28 1 engage policymakers possible responses climate change including taxation regulation carbon trading
Yes 
Yes engage policymakers climate change issues different levels Ongoing discussions held federal provincial governments regarding issues CO2 EOR fiscal regulatory regime required promote support pilot projects provide impetus commercial scale CO2 EOR projects proceed carbon sequestration discussions held fiscal regulatory technical challenges hurdles currently preclude physical injection testing proceeding Environmental Advisor ARC sits CAPPs Climate Change Working Group (CCWG) CAPPs Upstream Oil & Gas Climate Change Task Force (TWG) CCWG meets regular basis discuss current climate change regulatory landscape pertains member companies CAPP Provincial national policies analyzed group discusses CAPPs response policies aims develop workable solutions active engagement Government officials TWG sub group CCWG focuses strictly upstream industry group works concert Federal Government representatives develop national climate policy

 
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