044 Recommended guidelines for emission and … · Determination of CH4 emission factors from...

044 – Recommended guidelines for emission and discharge reporting

The Norwegian Oil and Gas Association, Recommended guidelines for discharge and emission reporting

No: 44 Established: 03.12.2004 Revision no: 16 Revision date: 08.01.2018 Page: 2

FOREWORD

ThisguidelineisrecommendedbyTheNorwegianOilandGasAssociation’sprofessionalnetworkforemissionsreporting(EEHReferencegroup)andbytheNorwegianOilandGasAssociationspanelforEnvironment.FurthermoreitisapprovedbytheCEO.Duringthisyear’supdatingoftheguidelinesrepresentativesoftheEEHReferencegrouphavebeenconsulted,andgiventheopportunitytoprovideinput.All,orrelevantparts,ofthisguidelinearesenttogovernments(NorwegianEnvironmentAgency,NorwegianPetroleumDirectorate,NorwegianRadiationProtectionAuthority)andNorwegianAssociationforhazardouswaste(NFFA)forcomments/information.ThetechnicaldirectoroftheworkinggroupistheNorwegianOilandGasAssociations’sHSEtechnicaldirectorandcanbecontactedviatheNorwegianOilandGasAssociation'sswitchboard+4751846500.ThisNorwegianOilandGasAssociationguidelineisdevelopedwithbroadpetroleumindustryparticipationbyinterestedpartiesintheNorwegianpetroleumindustry.ItisownedbytheNorwegianpetroleumindustry,representedbyNorwegianOilandGasAssociation.TheadministrationissubjecttoNorwegianOilandGasAssociation.NorwegianOilandGasAssociationVassbotnen1,4313SandnesPOBox80654068StavangerPhone:+4751846500Fax:+4751846501Homepage:www.norskoljeoggass.noE‐mail:[email protected]



CONTENT

FOREWORD..............................................................................................................................2

Content.......................................................................................................................................3

INTRODUCTION......................................................................................................................7

Purpose ..................................................................................................................................... 7 Abbreviations ............................................................................................................................ 7 References ................................................................................................................................ 8

PARTIREPORTINGTONORWEGIANENVIRONMENTAGENCY/NPD..........9

Which facilities and activities that should be reported ............................................................ 9 Quality assurance of data ....................................................................................................... 10 Reporting Process ................................................................................................................... 10

1 THEFIELD’SSTATUS...................................................................................................12

Definitions and explanations ............................................................................................ 12 Reporting Tables to EEH ................................................................................................... 13

2 DISCHARGESFROMDRILLING................................................................................14

Definitions and explanations ............................................................................................ 14 General ............................................................................................................................................. 14 Drilling with water‐based drilling fluids ............................................................................................ 14 Drilling with oil‐based drilling fluids ................................................................................................. 15 Drilling with synthetic fluids ............................................................................................................. 15

Reporting Tables in EEH ................................................................................................... 15 Calculation Methodology ................................................................................................. 16

General ............................................................................................................................................. 16 Calculation of theoretical hole volume ............................................................................................ 16

Flowchart for data collection ........................................................................................... 17

3 DISCHARGEOFOILYWATER...................................................................................18

Definitions and explanations ............................................................................................ 18 General ............................................................................................................................................. 18 Produced water ................................................................................................................................ 18 Displacement Water ......................................................................................................................... 20 Drainage water ................................................................................................................................. 20 Other oily water ............................................................................................................................... 20 Jetting ............................................................................................................................................... 20

Reporting Tables to EEH ................................................................................................... 20 Oily water ......................................................................................................................................... 20 Jetting ............................................................................................................................................... 21 Analysis of dissolved components in produced water ..................................................................... 21

Calculation Methodology ................................................................................................. 22 Water balance .................................................................................................................................. 22 Oil concentration .............................................................................................................................. 22



Oil to sea from jetting ....................................................................................................................... 22 Flowchart for data collection ........................................................................................... 23

4 USEANDDISCHARGEOFCHEMICALS.................................................................24

Definitions and explanations ............................................................................................ 24 General ............................................................................................................................................. 24 Exceptions ........................................................................................................................................ 25 Application area A – Drilling and well chemicals .............................................................................. 25 Application area B ‐ Production Chemicals ....................................................................................... 26 Application area C ‐ Injection Chemicals .......................................................................................... 26 Application area D ‐ Pipeline Chemicals ........................................................................................... 26 Application area E – Gas Treatment Chemicals ................................................................................ 26 Application area F ‐ Utility Chemicals ............................................................................................... 27 Application area G – Chemicals added to the export stream ........................................................... 27 Application area H – Chemicals from other production sites ........................................................... 27 Application area K – Trace elements ................................................................................................ 28

Reporting Tables to EEH ................................................................................................... 28 Calculation Methodology ................................................................................................. 30

Calculation of discharges and re‐injection of chemicals in Application A ......................................... 30 Calculation of emissions and re‐injection of chemicals from application area B and H ................... 30

Flowchart for data collection ........................................................................................... 31

5 EVALUATIONOFCHEMICALS..................................................................................32

Definitions and explanations ............................................................................................ 32 Reporting Tables to EEH ................................................................................................... 35 Calculation Methodology ................................................................................................. 36 Flow chart for data collection........................................................................................... 37

6 USEANDDISCHARGEOFHAZARDOUSSUBSTANCE.....................................38

Chemicals that contain hazardous substances ................................................................. 38 Compounds on the Priority List, as additives and contaminants in products ................................... 38

Reporting Tables in EEH ................................................................................................... 39 Calculation Methodology ................................................................................................. 40 Flowchart for data collection ........................................................................................... 40

7 EMISSIONSTOAIR........................................................................................................41

Definitions and explanations ............................................................................................ 41 Combustion sources ......................................................................................................................... 41 Combustion of gas ............................................................................................................................ 41 Combustion of diesel ........................................................................................................................ 42 Flare .................................................................................................................................................. 42 Well test ........................................................................................................................................... 42 Emissions from storage and loading of oil ........................................................................................ 42 Direct emissions of methane and NMVOC ....................................................................................... 42 Emission Components ...................................................................................................................... 45 Emission factors................................................................................................................................ 46

Reporting Tables to EEH ................................................................................................... 47 Combustion Operations ................................................................................................................... 48 Loading and unloading of crude oil .................................................................................................. 48 Direct emissions of methane and NMVOC ....................................................................................... 49 Well Test ........................................................................................................................................... 49 Gas tracer ......................................................................................................................................... 49



Calculation Methodology ................................................................................................. 50 Emissions from combustion ............................................................................................................. 50 Determination of CO2 emission factor of combustion ..................................................................... 50 Determination of NOx emission factor ............................................................................................. 51 Determination of SOx emissions factor from combustion of gas...................................................... 52 Determination of SOx emission factor from combustion of diesel and fuel oil ................................ 53 Determination of CH4 emission factors from combustion ................................................................ 54 Determination of nmVOC emission factors from combustion ......................................................... 54 Determination of the fallout of oil from the well test ...................................................................... 54 Determination of emissions from loading and storage of oil ........................................................... 54 Well Test ........................................................................................................................................... 55

Flowchart for data collection ........................................................................................... 56 Emission from combustion ............................................................................................................... 56 Emission from loading and storage of crude oil ............................................................................... 57 Direct Emissions of methane and NMVOC ....................................................................................... 58

8 ACCIDENTALDISCHARGES.......................................................................................59

Definitions and explanations ............................................................................................ 59 General ............................................................................................................................................. 59 Accidental oil discharges .................................................................................................................. 59 Accidental spills of chemicals ........................................................................................................... 60 Accidental gas emissions .................................................................................................................. 61

Reporting Tables for EEH .................................................................................................. 61 Unintentional discharges to sea ....................................................................................................... 61 Evaluation of unintentional discharges to sea .................................................................................. 61 Unintentional emissions to air .......................................................................................................... 62

Calculation Methodology ................................................................................................. 62 Flowchart for data collection ........................................................................................... 63

9 WASTE................................................................................................................................64

Definitions and explanations ............................................................................................ 64 General ............................................................................................................................................. 64 Segregated waste ............................................................................................................................. 64 Hazardous Waste .............................................................................................................................. 64

Reporting Tables to EEH ................................................................................................... 65 Segregated waste ............................................................................................................................. 65 Hazardous Waste .............................................................................................................................. 66

Calculation Methodology ................................................................................................. 66 Flowchart for data collection ........................................................................................... 67

PARTIIREPORTINGTOTHENRPA............................................................................68

10 INFORMATION.........................................................................................................69

11 DISCHARGESOFRADIOACTIVESUBSTANCESWITHPRODUCEDWATER69

Reporting Requirements ...................................................................................... 69 Reporting Tables to EEH ....................................................................................... 69 Reporting Tables .................................................................................................. 70

12 USEANDRELEASEOFRADIOACTIVETRACEELEMENT......................71

Reporting Requirements ...................................................................................... 71



Reporting Tables to EEH ....................................................................................... 71 Reporting Tables .................................................................................................. 71

13 ACCIDENTALDISCHARGES,ACCIDENTETC..............................................72

14 WASTE.........................................................................................................................73

Reporting Tables for EEH ..................................................................................... 73 Reporting Tables .................................................................................................. 74

PARTIIIREPORTINGTOTHENORWEGIANOILANDGASASSOCIATION75

15 Mitigationmeasures..............................................................................................75

Reporting Tables to EEH ....................................................................................... 79 Mitigation measures ......................................................................................................................... 79

LISTOFTABLES..................................................................................................................80

LISTOFFIGURES.................................................................................................................81

APPENDIXAHIGHLIGHTINGOFCHANGES............................................................82

Summary ................................................................................................................................. 82

APPENDIXBHANDBOOKFORQUANTIFICATIONOFDIRECTMETHANEANDNMVOCEMISSIONS............................................................................................................83



INTRODUCTION

Purpose

Since1997,allOperatorsontheNorwegianContinentalShelfhavesubmittedemissionsreportstoNorwegianEnvironmentAgencyandNorwegianOilandGasAssociation.Thishasbeeninapre‐definedformatandhaspreviouslybeendoneonspreadsheetsandpaperreports.The2003reportwasthefirsttimethatemissionsanddischargedatawerereportedelectronicallytoEnvironmentWeb(EW).Thereportingwillfrom2014foremissionsin2013beinanewsystem,EPIMEnvironmentalHub(EEH).Theseguidelineshavebeenpreparedtoaidinreportingandasareferencefortheindividualdatatobereported.TheguidelinesgothroughrequirementsoftheemissionsanddischargereportandthedatatablesthatshallbereportedtoEEH. EEH is on the address: https://www.environmenthub.no/ GuidanceforuseofEEHisgiveninEEH’usermanual.TheseguidelineswillserveasanextensionofinformationprovidedinM107‐2016GuidelinesforreportingfromoffshorepetroleumactivitiesfromtheNorwegianEnvironmentAgency1.Theseguidelineswillhelpensureaconsistentemissionanddischargereportingfromalllicenseswithcleardefinitionsinaccordancewithanunambiguousformat.

Abbreviations

BOP Blow Out Preventer CHARM Chemical Hazard Assessment and Risk Management; A tool for mutual comparison of

offshore chemicals and expected damage potential CH4 Methane CO Carbon monoxide CO2 Carbon dioxide EEH EPIM Environmental Hub EPIM EPIM E&P Information Management Association HOCNF Harmonised Offshore Chemical Notification Format. Format for chemical documentation

defined by OSPAR. nmVOC Non-Methane Volatile Organic Compounds NORM Naturally occuring radioactive material. NOROG Norwegian Oil and Gas Association NORSAS Norwegian Resource Centre for Waste and Recycling N2O Nitrogen dioxide NOx Nitrogen oxide NPD Norwegian Petroleum Directorate. NRPA Norwegian Radiation Protection Authority. NS Norwegian Standard OGP International Association of Oil & Gas Producers OSPAR Oslo-Paris Convention for the protection of the Marine Environment of the North-East

Atlantic and Oslo-Paris Commission for the protection of the Marine Environment of the North East Atlantic

PAH Polyaromatic hydrocarbons PCB Polychlorinated biphenyls PDO Plan for development and operation

1http://www.miljodirektoratet.no/Documents/publikasjoner/M107/M107.pdf



PEMS Predictive Emission Monitoring System PLONOR Pose Little Or No Risk to the Marine Environment. A list of OSPAR chemicals assumed to

have little or no effect on the marine environment by discharges PTIL Petroleum Safety Authority Norway SCR Selective catalytic reduction Sm3 Standard cubic metres. Standard conditions at 15OC at 1 atmosphere SOx Sulfur oxides TAD Norwegian Customs and Excise

References

AkerEngineering.«Directhydrocarbongasemissionsfromproductionandriserplatforms»,1993,enstudieutførtifm.OLFmiljøprogram,faseII.Forskriftomgjenvinningogbehandlingavavfall(avfallsforskriften).FOR‐2004‐06‐01‐930.(Norwegianonly)Forskriftomklassifisering,merkingmv.avfarligekjemikalier.FOR‐2002‐07‐16‐1139.(Norwegianonly)Forskriftomkvotepliktoghandelmedkvoterforutslippavklimagasser(klimakvoteforskriften).FOR‐2004‐12‐23‐1851.(Norwegianonly)Forskriftomsæravgifter.FOR‐2001‐12‐11‐1451(Norwegianonly)Regulationsrelatingtoconductingpetroleumactivities.(Theactivitiesregulations).FOR‐2010‐04‐29‐613.ISO/IECGuide98‐3:2008,Guidetotheexpressionofuncertaintyinmeasurement(GUM).Lovompetroleumsvirksomheten(petroleumsloven).LOV‐2012‐12‐14‐80.(Norwegianonly)EnvironmentListofPrioritySubstances.Availablefrom:http://www.miljostatus.no/tema/kjemikalier/prioritetslisten/NORSAS.Radioaktivtavfall.Availablefrom:http://www.norsas.no/Radioaktivt‐avfall(Norwegianonly)NORSAS.Veiledningominnleveringogdeklareringavfarligavfall,utgave2012.(Norwegianonly)NORSOKS‐003EnvironmentalCare,2017.NorwegianEnvironmentAgency.M107‐2016Retningslinjerforrapporteringfrapetroleumsvirksomhettilhavs.(Norwegianonly)NorwegianOilandGasAssociation.085Anbefalteretningslinjerforprøvetakingoganalyseavprodusertvann.(Norwegianonly)NorwegianOilandGasAssociation.EnvironmentalProgrammePhaseII,ProjectC01.EmissionsandDischargesfromWelltesting,avKjelforeningenNorskEnergi.31.05.1994.NorwegianOilandGasAssociation.Håndbokforkvantifiseringavdirektemetan‐ogNMVOC‐utslipp.(Norwegianonly)NorwegianOilandGasAssociation.093Recommendedguidelinesforwastemanagementintheoffshoreindustry.NorwegianPetroleumDirectorate.Establishedpracticeforwelldesignation.Availablefrom:http://www.npd.no/no/Tema/Bronner/Temaartikler/Bronnklassifisering/NorwegianRadiationProtectionAuthority.Retningslinjerforrapporteringavradioaktivestofferfrapetroleumsvirksomheten.Availablefrom:http://www.nrpa.no/dav/6aeae50868.pdf(Norwegianonly)NorwegianStandard9377‐2:200Vannundersøkelse–Bestemmelseavoljeivann–Del2(Norwegianonly)NorwegianStandard9431:2011Classificatonofwaste.(Norwegianonly)http://npd.no/en/Topics/Wells/Temaartikler/Established‐practice‐for‐well‐designation/OSPAR.OSPARGuidelinesforCompletingtheHarmonisedOffshoreChemicalNotificationFormat(HOCNF).OSPAR.Plonorlist.Availablefrom:http://www.cefas.defra.gov.uk/media/29136/13‐06e_plonor.pdfPetroleumSafetyAuthorityNorway.Guidelinesregardingthemanagementregulations.



PARTIREPORTINGTONORWEGIANENVIRONMENTAGENCY/NPD

Whichfacilitiesandactivitiesthatshouldbereported

TheemissionsreportshallmeetthereportingrequirementsofbothNorwegianEnvironmentAgencyandNPD.ThereportingshallbeperformedaccordingtothePetroleumAct'sdefinitionofpetroleumactivity.Thisincludes:

Permanentinstallations(fixedinstallations).Thereportingshallalsoincludetheinstallationphase. Mobilefacilitieswhentheyareonlocation,suchasdrillingrigs,wellinterventionfacility(subsea)and

more.Mobilefacilitiesaredefinedasnotincludedaspartofthepermanentdevelopmentplanandthattheyhavenophysicalconnectiontothepermanentdevicewithabridgeconnectionetc.

Combinedfacilitiesflotel/craneifthemainfunctionisflotel. Wellstimulation‐/processingfacilitieswhentheseareconnectedtothewell. Transportationsystems OnshoreterminalsthataredefinedaspartofthepetroleumactivitiesinthePetroleumAct,including

processing,compressionofgasforonwardtransportandloadingofcrudeoil/condensateandnaphtha.Thedistinctionbetweenpetroleumactivitiesononehandandprocessing/refiningontheothersideshallfollowtheCompanyPetroleumTaxboundaries.

Emissionsfromrefineriesandotheronshorefacilitiesshouldbereportedaccordingto"corporateself‐reporting"inAltinn,asrequiredforland‐basedindustries.AccordingtoNPD,specificinformationtoEEHforemissionstoairshallbegivenforsomeplant/activitiesaslistedbelow:

B11 1) Emissions to air from the compression of dry gas(Kårstø), and the Draupner installation

The processing plant at Kollsnes (Gassled E) Emissions to air for the entire facility Mongstad Loading of non-processed products (nmVOC and CH4) Sture (Oseberg Transport System) Loading of non-processed products (nmVOC and CH4), and the oil heater

(CO2 and NOx) Gassled D (Kårstø) Emissions related to gas compression for further transport (all emissions)

and emissions associated with loading condensate and naphtha (only nmVOC andCH4)

The processing plant at Ormen Lange Loading of non-value-added products (nmVOC and CH4), and boilers and diesel engines(CO2 and NOx)

The Snøhvit LNG processing plant Emissions to air for the entire facility 1) B11 (riser platform Norpipe pipeline to Emden in Germany, located on the German continental shelf)

and Draupner (riser platform for the PrimePipe, Zeepipe1 and2B, Euro Pipe1 and Norfra). Allfieldsshall,accordingtoNPD'sdefinition,deliveraseparateannualreport,evenifithasnotbeenanyemissionsordischarges.Forsatellitefieldsthatproducethroughanotherfield(suchasStatfjordNorththatproducesthroughStatfjord),emissionsanddischargeswillbereportedforthefieldwherethedischargesoccur.Mobilefacilitiesthatconductdrillingorwelloperationswillreportunderthefieldwherethewell(s)is/areconnected.AseparatereportmustbesubmittedfortheOperator'sexplorationactivity.The“Field"whereemissionshaveoccurred(TheOperatorExplorationActivity),shallbesummedupinoneoverallemissionsreportforexploration,Example:"ExplorationOperatorAS".Fordrilling,alldatarefertothewellboreand/orthefacilitythatperformsdrilling(drillingrig,whetheritisamobileor(inrarecases)afixedinstallation).Forwellsdrilledoveryear‐endthecompaniesmaychoosetoreportfortheyearinwhichthedischargesoccurs,orreportfortheyearthewelliscompleted.Reportingmethod,calculationmethodsandwhichdatathatismovedshallbedescribedintheemissionsreport.Thereshallbeprovidedacontactpersonforthereport.



Qualityassuranceofdata

TomakesurethattheGovernmentandtheindustrycanestablishandmaintainasufficientoverviewoftheindustry'stotalemissions,thequalityofthereporteddataneedstobesatisfactory.Thismeansthat:

Allreportableemissionsanddischargesfromtheactivitiesmustbeincludedandemissionreportsmustbecomplete.

Emissionsdataandotherinformationreportedmustbeaccurate.Thismeansthatemissionsmustbecalculatedusingwell‐knownmethods,withtheappropriateemissionfactorsandthecalculationsmustbefreeoferrors.

Emissionsfiguresmustbepresentedusingadoptedstandardforunits,namingandterminology.TheOperatorisresponsibleforqualitycontrolofalldataintheemissionsreport.IncaseswherecontractorsreportdirectlytotheOperator(e.g.chemicalsuppliersandwastecontractors),theOperatorisresponsibleforensuringthattheevaluationandcontrolproceduresthesubcontractorsuseareadequate,andthatdatacollectioniscomplete.AnalysisofthedischargestreamsasabasisfortheestablishmentofdischargedatacanbecarriedoutbytheOperatororbyanindependentlaboratory.TheNorwegianEnvironmentAgencyrequiresanapprovedaccreditationtoacceptdischargeanalysisfromanindependentlaboratory.Theemissionsanddischargereportshallgiveapictureoftheactivity,emissionsanddischargesforthefieldforthereportingyearaswellastrendsovertime.Itwouldthereforebeusefultohavehistoricaltrendsandforecastspresentedingraphformsinthereport.Substantialchangesinemissionsordischargesovertimeshouldbecommented.ConversionfactorsandcalculationsmustbedocumentedbytheindividualOperator.

ReportingProcess

Thereportingprocesshaschangedcomparedtoearlieryears: DataisuploadedtoEEH Theuserhastomarkatableascompletewhenthedataarecomplete Theusercanthenuploadthereportandpublishthedata Thedatacanbere‐publishedasoftenasrequireduntil15thofMarch Whentheemissionsanddischargereportforthefieldiscompleted,deadlinethe15thofMarch,thereport

anddatamustbepublishedinEEH,andtheEnvironmentAgencyandNRPAwillstartreviewingthereporteddata.

Fromthisdatetheemissionanddischargereportcanbeassumedaspublic,butthepdfreportswillnotbepublishedontheNOROGwebpageuntil1stofMay.

Thedatacanbeupdatedaslongasrequired,butanyupdateswillnotbeavailableforanyotherpartiesuntilEPIMorNOROGhavebeeninformedaboutthechangesandtheneedforpublishingnewdataandreport.

Thedatacanbesentbacktotheoperatorforupdatingifanyerrorsorquestionsaboutconfirmation.Theoperatorcanalsochangethereportafter15thofMarch,but

UnlesstheEnvironmentAgencydemandsit,itisnotnecessarytoupdatethepdfreportwithchangesafter15thofMarch.Ifthisisneededitmustappearclearlyfromthereportwhatthechangesare.

NotethatreportingtotheNorwegianEnvironmentAgencyandtheNorwegianRadiationProtectionAuthorityisnowsplit.Previously,hazardouswasteincludingradioactivewastewasreportedinthesametable,'HazardousWasteOther'andinformationfromthetablewerereportedtoboththeNorwegianEnvironmentAgencyandtheNorwegianRadiationProtectionAuthority.Nowtherearetwoinputtablesforhazardouswaste;'HazardousWaste'inchapter9and'RadioactiveWaste'inChapter14,whicharereportedseparatelyfortheEnvironmentDirectorateandtheNorwegianRadiationProtectionAuthority.



Table1Deadlinesforthevariousstepsinthereportingprocess.Step Action Deadline

1 Update of information about operator, field, facility, wellbore etc. by NPD Synchronized

continuously

2 Reporting by the operator 15th of March 3 Review by Environment Agency and NRPA 15th of March 4 Update of erroneous data ASAP

Thefollowingtableliststherelevantcontacts.

Table2ContactsforquestionsAgency Contact person e-mail address Telephone Norwegian Oil and Gas Association Egil Dragsund [email protected] 970 26 956 NPD Rune Hult [email protected] 51 87 60 77 NRPA Eivind A. Stubø [email protected] 67 16 25 00 Norwegian Environment Agency Switchboard

Ingeborg Rønning [email protected]

03400 465 45 921

EPIM Tor Inge Gran [email protected] 900 85 272 SystemerrorsinEEHareautomaticallyreporteddirectlyfromEEH.Theusercanalsogethelpbychoosing‘Gethelp’anddescribetheprobleminthedialoguewindowthatappears.



1 THEFIELD’SSTATUS

Thischaptershallgiveageneraloverviewofthefield,andbackgroundinformationontheemissionsanddischarges.Thechaptershouldbeconciseandinformative.

Definitionsandexplanations

TheOperatorshallprovideabriefandgeneraldescriptionofthefield.Amongotherthings:

Whatinstallations(orwells)thereportincludes Changesrelatingtotheinstallationscomparedtothepreviousyear'sreporting Overviewofdischargepermitsforthefield Whichinterfacesthefieldhaswithotherfields YearofPDOandproductionstartandexpectedcompletiondate Expectedmajorchangesinthecomingyear Howoil,gasandcondensatearetransported,andwhere

Deviationsfromthegivenrequirementsordemandsistobereported.TheOperatorshalldescribeanychangestotheplansandmeasuresforthezerodischargework.Atableofchemicalsprioritizedforsubstitutionshallbeincluded.Itshouldcontainthefollowinginformation:Table3OverviewofwhichchemicalsaccordingtoNorwegianEnvironmentAgencyrequirementsshallbeprioritizedforsubstitution

Chemical substitution (Trade Name)

Category number* Status New chemical (Trade Name)

Operator deadline

*AccordingtoTable16.(Table5.1inM107‐2016)

Ifariskassessmentiscarriedoutforproducedwater,Table10.4shallbefilledinaccordingtoM‐107.(Newtable:riskassessmentandtechnologyassessmentforproducedwater).Inaddition,asummaryoftheevaluationandstatusofanyadoptedmeasuresshallbegiven. Thehistoricalandforecastedproductionshallbeillustrated.ThisinformationisavailablefromtheannualreportstotheRevisedNationalBudget(RNB)totheNPD.Thetablebelowshowstheconversionofproducedquantitiesofoilequivalents(Sm3o.e.)accordingtoNPD’scurrentnorm:Table4NPDconversionfactorsofoilequivalent

Petroleum Product Converted from Converted to oil equivalent (o.e.)

Oil 1 Sm3 1 Sm3 o.e. Condensate 1 ton 1.3 Sm3 o.e. Condensate 1 Sm3 1 Sm3 o.e. NGL 1 ton 1.9 Sm3 o.e. Gas 1000 Sm3 1 Sm3 o.e.



ReportingTablestoEEH

All tables with production numbers that should be reported to EEH for Chapter 1 are synchronized with NPD’s database DISKOS: https://portal.diskos.cgg.com/prod‐report‐module/. This forms the basis for the tables: 1.0a Status consumption 1.0b Status production Table5EEHinputTable:ProducedWaterRiskAssessment(table10.4inM‐107)

Column Title Normal Value / Content Operator The name of the Operator StructureType ProducedWaterRiskAssessment ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Device name as provided by NPD Location Name of drilling location

ChemicalAnalysis

Select ‘Yes’ if it is done in accordance with regulatory requirements, it may have been done in previous years, but it must be less than 5 years since the last time and no significant changes.

WetTesting


WetAssesment


SubstanceBased LargestContributor Only the largest contributor should be given. TechAssessment

EIF

Enter value if it is done in accordance with regulatory requirements. It may have been done in previous years, but it must be less than 5 years since the last time and no significant changes.

BatAssessment* MeasuresImplemented Measures that are implemented Comment

*Notethatthereisamistakeintable10‐4inM107,bothBATandBEPareincluded,butitisonlyBATthatshouldbeincluded.

EEH‐table updates in chapter 1 No updates.



2 DISCHARGESFROMDRILLING

Thischapterwillprovideinformationondrillingwithwater‐based,oil‐basedandsyntheticdrillingfluids.Furthermore,thedisposalofwastegeneratedduringdrillingshallbedescribed.Acutepollutionfromdrillingshallnotbereportedhere,butundersection8.2.Inthischapter,drillingfluids(mud)andcuttingsshallbereported.Itshallbereportedperwellbore/mudsystem,notpersections.Allcuttings/mudshallbereported,includingcuttings/mudfromdrillingwithopenmudsystem(withnorisers).Thisshallbereportedforbothexplorationanddevelopmentwells.So‐called"shallowwells"arenotreportable.Thesearewellsthataredrilledtotestequipmentortoobtaininformationontherockcharacteristics,andnormallynotdeeperthan200metres.MoreinformationaboutwellclassificationisgivenintheNPD’stopicpages.2Wellsdrilledoverayear‐endcaneitherbereportedintheyearthedischargeoccurs,ortheyearinwhichthewelliscompleted.Whichreportingmethodselectedwillbedescribedinthenemissionanddischargereport.DatamustbeallocatedtothecurrentreportingyeartosubmitreportsthisdatatoEEH.Theuncertaintyoftheindividualemissionsshouldbebrieflyexplained.


General Cuttings/drillingfluidfromdrillingthatisdischargedoffshoreortreatedonshore/offshoreshallbereportedinthischapter.Theamountofcuttings/mudthatissenttoshorefordisposalmustalsobereportedashazardouswasteinchapter9.Theamountofdrillingfluidthatisreturnedtothedrillingfluidsupplierforreuseshallnotbeincludedinthereporting.

The extent of reuse of drilling mud shall briefly be explained. It should be quantified if possible.

Drillingwithwater‐baseddrillingfluids

Water‐baseddrillingfluidsareusedwheretechnicallyfeasible.Itisgenerallypermissibletoreleasecuttingswithwater‐baseddrillingfluids. 2 http://www.npd.no/no/Tema/Bronner/Temaartikler/Bronnklassifisering/

Note regarding the amount of waste generated and the amount of waste handled: There is not necessarily a correlation between the quantity of drilling waste in chapters 2 and 9, although the waste originates from identical drilling operations. There are three reasons for this:

Lags in recording and reporting. Waste generated in one year could eventually be treated in a waste treatment plant the following year.

The data in chapter 2 are estimated values from offshore drilling operations while in chapter 9 the values are based on actual weight

o In table 2.2 and 2.4 in the annual report total amount of cuttings is calculated from theoretical hole volume and hole factor. Drilling fluid is not included here.

o Imported and exported cuttings in chapter 2 contains cuttings with appendages of drilling fluid o Drilling waste given in chapter 9 is weighted amount of cuttings with appendages of drilling fluid

The waste is transported to shore. There may be minor adjustments to the amount of waste due to changes in the moisture content of the waste.

The Operator should have procedures to ensure that reporting of waste is consistent and complete, and that there is no double reporting.



Drillingwithoil‐baseddrillingfluidsOil‐baseddrillingfluidisnormallyusedforsectionsinthewelldemandingparticularlyhightechnicalcharacteristicsofthedrillingfluid.Itisnormallynotallowedtodischargecuttingsgeneratedbytheuseofoil‐baseddrillingfluids,butapermissiontodischargecuttingsmaybegrantedfornon‐sensitiveareas,ifthecuttingshaveanattachmentofoilnohigherthan1weightpercentbasedonthecuttingsdryweight.Whendrillingwithoil‐baseddrillingfluids,thecuttingsactasawaterrepellingputtymassthatwillsettleontheseabedwhendischarged.Cuttingsareanalyzedbyaretortanalysiswhichdeterminestheamountofoil,waterandsolids.Totalamountofdrysubstancesarethesumofcleancuttings(i.e.drilled‐outrockfromtheformation)plusthedrysubstancesfromthedrillingfluid(whichincludesweightingmaterials,clayandsalts).Resultsfromtheretortanalysesshallbeweightedaveragevaluesforthecurrentsection.Thereisnoneedtospecifythisinmoredetailinthereport,buttheinformationandcalculationsshallbeavailableforinternal/externalaudits.

DrillingwithsyntheticfluidsSyntheticfluidsarenormallyesterorolefinbased.Differenttypesofsyntheticdrillingfluidsarereportedinthesametable.NorwegianEnvironmentAgencymaygivepermissiontodischargecuttingswithappendagesofsyntheticdrillingfluids.Permissionisnotgiventodischargepuresyntheticdrillingfluidsoruntreatedcuttings.Syntheticdrillingfluidsaremostlynolongerinuse.Syntheticfluidsarereportedanddocumentedsimilarlytooil‐baseddrillingfluids.

ReportingTablesinEEH

Table6EEHinputtable:Drilling

Column Title Normal Value/ Content Operator Name of the operating company StructureType Drilling ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Wellbore Well bore name given by NPD MudSystem Water, oil- og synthetic based system Length (m) The well's length (depth) TheoreticalHoleVolume (m3) Theoretical hole volume HoleFactor (tonnes/m3) Hole factor MudDischarged (tonnes) Discharge of drilling fluid as appendage to cuttings MudInjected (tonnes) Drilling fluid as appendages of cuttings injected MudSentOnshore (tonnes) Drilling fluid sent onshore as waste




Column Title Normal Value/ Content MudLeftOrLost (tonnes) Drilling fluid left in the formation or lost to the formation CuttingsWithMudExportedToOtherFields (tonnes) Cuttings with appendages sent to other fields CuttingsWithMudImportedFromOtherFields (tonnes) Cuttings with appendages imported from other fields CuttingsWithoutMudDischarged (tonnes) Discharge of cuttings CuttingsWithoutMudInjected (tonnes) Injection of cuttings CuttingsWithoutMudSentOnshore (tonnes) Cuttings sent onshore AverageOilOnCuttingsDischarged (g/kg) Average concentration of oil on cuttings discharged to sea [g/kg]*

*NB! The requirement in the Activities Regulations §68 states that there should be maximum 10 g oil/kg dry substance. Amount of dry substance are not reported and concentration given here is therefore not per kg of dry matter, but per total amount of cuttings.

CalculationMethodology

GeneralTheDrillingOperatornormallyhasamassbalanceaccountingfordrillingfluidsandcuttings.TheOperatorshouldcalculateeachsectionofthewell,andthenaddthemtogethertoobtaintherequireddataforeachwell.Oneneedsthedensityofthedrillingfluidforeachsectiontocalculatethemass.

CalculationoftheoreticalholevolumeTheoreticalholevolumeiscalculatedfromthediameteroftheindividualsectionsandthelengthofeachsection:

LengthD

THV **10054,2

*2

2

Table7Explanationofthecomponentsintheequationforcalculatingthetheoreticalholevolume.Equation(1).

Component Unit Description THV m3 Theoretical hole volume D “ Section diameter in inches Length m Length of section



Flowchartfordatacollection

Enter data for volumes and chemicals in the reporting system (Environmental accounting).

Normally done by Drilling Contractor, or data transmitted from the Drilling Contractor.

Make calculations per section. Add up to well level for each well.

Notify the responsible Adjust data

Not approved

Generating EEH tables. Report

to the EEH according to EEH routines

Annual reporting to EEH. Writing comments and drawing graphs

Extraction of data from the environmental accounting system. Align

with Chapter 4 for chemicals

Generate reports (KPIs etc.)

Quality Assurance Is there a mass balance for all mud and cuttings?

Are all wells included? Are all sections included?

Are all imported fluids included?

Do drilling fluid and amount of cuttings match with drilling activity?

Are there drilling activities in the previous year to be included now

because the well was not completed in the previous

reporting year?

Has there been any discharge of synthetic or oil based mud that must be treated as a deviation?

+ internal routines for quality assurance

Yearly data OK



3 DISCHARGEOFOILYWATER


GeneralThischaptershallgiveanexplanationofthedischargestreamsforthefieldandhoweachdischargestreamistreated.Dischargesourceswillnormallybe:

Producedwater(formationwaterandcondensedwater) Displacementwater(ballastwater)fromstoragefacilitiesforoil Drainagewater,whichcanalsoincludewaterusedforflushingoftanksandotheroilywastewaterifitis

treatedinthesamesystemasthedrainagewater. Oil‐contaminatedwaterassociatedwithsandcleaning(jetting). Otheroilywater

Ifalargeproportionofhazardoussubstancesaredischargedtogetherwithsomeofthedischargestreamsthisshallbereported.Thequantificationlimitforeachsubstanceshallbespecified.Whencalculatingthequantityofsubstancesdischarged,field‐specificfactorsbasedonmeasuredconcentrationsintheproducedwatershallbeused.Forfieldswithonesingledischargepermit,butseveralinstallations,thetotaldischargesfromthefieldshallbereportedinthischapter.Accidentaldischargesofoilarenotreportedinthischapter,butinchapter8.Inthetables,boththeamountofoilandtheoilconcentrationinthewatershallbereported.OilinwateranalysesshallbeperformedaccordingtoISOmethod(ISOEN9377‐2)orequivalentmethodsthatcanbecalibratedagainsttheISOmethod.Theamountofwaterdischargedshallbereported.Itisspecifiedthattheinjectedwatervolumesshallbeinjectedproducedwateronly,orotheroilcontaminatedwater.Injectedseawaterorsourcewater(forexample,waterfromtheUtsiraformation)shallnotbereportedtoEEH.EEHfacilitatesforreportingonedatasetperinstallationandwatertype.Wherethereareseveraldischargestreamsforthesamewatertypeandinstallationtheproportionalamounttototalemissionsmustbereportedsothetotaldischargesfromthefacilityandthefieldiscorrect.Thereportshallincludegraphsshowingthetrendintotaldischargesoftheindividualmaingroupsofdissolvedcomponentsinproducedwater.Majorchangesfromthepreviousyearshallbeexplained.The uncertainty of the individual emissions should be briefly explained.

ProducedwaterProducedwaterisformationwaterwhichisseparatedoutintheseparationprocessand/orwaterthatiscondensedintheproductionprocess.Thiswaterfollowstheoilandmustbeseparatedfromtheoilandthentreatedinanacceptablemanner.Producedwatercontainsthefollowinggroupsofsubstances:

Dispersedoil Organiccompoundsfromtheformation Inorganiccompoundsfromtheformation,bothdissolvedsaltsandprecipitates Chemicals Naturallyoccurringradioactivematerial(NORM)



Compositionandcontentofproducedwatervaryconsiderablyfromfieldtofield,andpartlyalsofromwelltowell.Informationaboutthecompositioncanonlybeestablishedthroughanalyses.Thereisalwaysoilindispersedforminproducedwater.Anumberofotherorganiccompoundsfromtheformationaredissolvedintheproducedwater,includingPAHcompounds,BTEX(benzene,toluene,ethylbenzeneandxylene),phenols,alkylphenolsandcarboxylicacids.Dissolvedinorganiccompoundsfromtheformationalsooccur.Thisismainlysaltsandheavymetals.Formationresidues(limestone,sandstone),occurtogetherwithcorrosionproductsanddeposits.Dischargesofdispersedoil,organiccompoundsandheavymetalsshallbereportedtotheNorwegianEnvironmentAgency.Producedwatercontainschemicaladditives.Thechemicalscancomefromthreesources:

Chemicalsmaybeinjectedintothewell,theoil/gasprocessorotherprocessesthatareassociatedwiththeproducedwatersystem.

Chemicalscanbeaddedtotheinjectedwaterthatcirculatesthroughthereservoirandreturnalongwiththewellstreamthroughproductionwells.

ChemicalscanbeaddedtotheproductionstreamfromupstreaminstallationsDischargesofchemicalsinproducedwatersshallbereportedtoNorwegianEnvironmentAgencyinchapter4.Thereportshallincludeabriefdescriptionoftreatmentmethodsandanalyticalmethods.Treatment:Producedwatershallcontainamaximumof30mgofdispersedoilperliterofwaterdischargedasaweightedmonthlyaverage.Itmustbepurifiedtoremoveexcessdispersedoil.Treatmentequipmentvariesandshallbedescribedinthereport.Thisincludeswatertreatmenttechnologyforcleaningthewatercondensedfromthegasproduction.Analysis:Dischargesofoilinproducedwaterisdeterminedbyanalysisusingcurrentstandards3.Theconcentrationofdispersedoilinwaterismeasuredinmg/litre.NorwegianEnvironmentAgencyencourageoperatorstouseinstrumentsthatprovideacontinuousanalysisofoilinwater,especiallytheeffluentfromproducedwater.NorwegianEnvironmentAgencywillnormallynotrequiremanualsamplingifcontinuousmeasurementisused.Totaldischargedproducedwatervolumeismeasuredbyflowmetreandisexpressedasm3.ConcentrationofheavymetalsandPAHcompounds,BTEX,phenols,alkylphenolsandcarboxylicacidsindischargesarealsodeterminedbyanalysisofproducedwater.Thedischargedquantitiesaredeterminedbythedischargeconcentrationsandmeasuredflowdischarged.NorwegianOilandGasAssociationrecommendsthatatleast2sampleswiththreereplicationseachyeararetakenforthedeterminationofdissolvedcomponentsinproducedwater3.Thecomponentstobeincludedinaproducedwateranalysisaregivenin

3 Fordetails,see‐NorwegianOilandGasAssociation.085RecommendedGuidelinesforsamplingandanalysesofproducedwater.



Table11.Thereportshouldincludegraphsorfiguresshowingthedevelopmentofdischargeconcentrationsinproducedwater.Majorchangesfromthepreviousyearmustbeexplainedinthereport.Dischargesofheavymetals,aromaticsandalkylphenolsshallbecalculatedonthebasisoftheamountofwaterdischarged.Waterexportedorinjectedshallnotbeincludedforthesedischarges,andproducedwateranalysisisnotrequiredforexportedorinjectedwatervolumes.Itisstillrecommendedtoanalysetheinjectedwater,aspartofthesurveyofvariousmeasuresinthe‘zerodischargetosea’work,andbecauseitisanadvantagefortheoperatorstoknowwhatthedischargesavingsfromsuchmeasureshasbeen.NaphthaleneAcidsisagroupofcompoundsthatoccurinsomefields.Itwouldthereforebeappropriatetopointthisoutinacommentunderthetable,sothatthisanalysisisreportedonlyforthosefieldswheredischargeofNaphthaleneAcidsisapplicable.

DisplacementWaterDisplacementwaterisseawaterusedtobalancetheoilinstoragetanks.Whenoilisloadedintothetanksthewaterisdisplacedandledtothesea.Seawaterisdrawnintothetankswhentheoilisoffloadedtoshuttletankers,toreplacetheoil.Dischargeofdisplacementwaterisdeterminedusingthesameprinciplesasproducedwater.Displacementwaterfromstoragetankswillnormallyinclude:

Dissolvedorganiccompoundsfromtheoil(mainlydispersedoil) Chemicalsaddedtotheoil.Someofthesearewatersolubleanddissolveinthedisplacementwater.

Thedisplacementwaterwillnormallycontainthesamelevelofinorganiccompoundsasseawater.OneshouldbeawareoftheformationofH2Sinthepresenceofsulphate‐reducingbacteria.Treatment:Thereisarequirementfortreatmentofdispersedoildowntoamaximumcontentof30mg/literofwater.Moststoragetankscurrentlymeetthisrequirementwithoutspecialtreatment.Therearenodischargestandardsforothersubstances.

DrainagewaterDrainagewaterisrainwater,washwaterandmore,whichisdirectedtoopenorcloseddrains.Drainagewatershallbetreatedbeforedischarge.Injectionisalsoanoptionforsomeinstallations.

OtheroilywaterIfanOperatorhasdischargesofoilywaterwhichisnotproducedwater,drainedwaterordisplacementwater,thisshouldbereportedas"otheroilywater."

JettingSandwillbedepositedintheseparatortanksduringtheseparationprocess.Thesandsettlesinthebottomoftheseparatortanks.Specialjetnozzleswashtheinsideofthetankstogetthesandout.Inmanycasestheproductionisstoppedduringajetoperation.Therearerequirementsfortreatmentofwaterandsandbeforedischarge.Forjetting,thetotaloildischargeandoilappendagesonsandshallbereported.Thismightcomefromdifferentsources.Oilinproducedwaterisonesource,ifproducedwaterisusedforjetting.Theremightalsobeanoilfilminsidetheseparatortankthatisflushedoutwiththewater.Dischargesexceedingthelimitduringjettingshallbementionedinthereport.Thelimitis1weightpercentoilappendagesonthesandperjob,basedondrymass.




NotethatproducedwaterreportedintheOilyWater‐tableandanalysisreportedintheProducedWaterAnalysis‐tablemustbeassociatedwiththesame‘DischargePoint’.

OilywaterTable8EEHinputtable:OilyWater

Column Title Normal Value / Content Operator Name of the operating company StructureType OilyWater ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location WaterType Produced/Drainage/Displacement/Other ReportMonth Month reported

DischargePoint Can be used to separate the emissions of installations with multiple emission points

WaterImported (m3) Water volumes imported WaterInjected (m3) Water volumes injected WaterExported (m3) Water volumes exported WaterToSea (m3) Water volumes discharged to sea OilConcentrationISOmethod (mg/l) Mean monthly oil concentration calibrated against ISO method

In the table data for all oily water, except water for jetting is reported.

JettingTable9EEHinputtable:Jetting

Column Title Normal Value / Content Operator Name of the operating company StructureType Jetting ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location ReportMonth Month reported OilOnSolidParticles (g/kg) Mean monthly oil concentration as appendage on sand OilToSea (tonnes) Amount of oil discharged during jetting, calibrated against IS method

AnalysisofdissolvedcomponentsinproducedwaterTable10EEHinputtable:ProducedWaterAnalysis

Column Title Normal Value / Content Operator The name of the Operator StructureType ProducedWaterAnalysis ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Device name as provided by NPD Location Name of drilling location




Column Title Normal Value / Content

DischargePoint Can be used to separate the emissions of installations with multiple emission points

Component The component in the produced water which was tested. See Table 10. SampleConcentration (g/m3) The concentration of the component in the sample DetectionLimit (g/m3) The detection limit of the respective component in the sample Laboratory Laboratory where the test is performed Technique The technique used in the analysis (for example GC) Methodology The method used in the analysis (such as an ISO method) SampleDate Date the sample was collected



Table11DissolvedcomponentsinproducedwatertobeanalyzedComponent Oil in water (Installation) C2-dibenzothiophene PHENOLS: INORGANIC ACIDS: NPD / BTEX: C3-dibenzothiophene Phenol naphtenic acidS Benzene 16-EPA-PAH C1-Alkylphenols HEAVY METALS: Toluene Acenaphthylene* C2-Alkylphenols Arsenic Ethyl benzene Acenaphtene* C3-Alkylphenols Lead Xylene Anthracene* C4-Alkylphenols Cadmium NPD / PAH: Fluorene* C5-Alkylphenols Copper Naphtalene Fluoranthene* C6-Alkylphenols Chromium C1-naphtalene Pyrene* C7-Alkylphenols Mercury C2-naphtalene Chrysene* C8-Alkylphenols Nickel C3-naphtalene Benzo(a)anthracene* C9-Alkylphenols Zink Phenantrene Benzo(a)pyrene* ORGANIC ACIDS: Iron C1- Phenantrene Benzo(g,h,i)perylene* Formic acid Barium C2- Phenantrene Benzo(b)fluoranthene* Acetic acid C3- Phenantrene Benzo(k)fluoranthene* Propionic acid Dibenzothiophene Indeno(1,2,3-c,d)pyrene* Butyric acid C1-dibenzothiophene Dibenz(a,h)anthracene* Valeric acid

*Thetotalsumofthegroup16‐EPA‐PAHshallbestatedinthereport.ThetotalsumofeachofthegroupsBTEX,PAH,NPD,phenols,organicacidsandheavymetalsshallbestatedinthereport.Naphtaleneandphenantreneisnotpartofthe16‐EPA‐PAH.AnthraceneismovedfromtheNPD‐PAHgrouptotheEPA‐PAH‐group.Radioactivity(226Ra,228Ra,210Pband228th)isremovedfromtable10,thisisnowincludedinchapter11.


WaterbalanceMakesurethereisawaterbalanceforallwatertypes:Generatedwater+Importedwater=Waterdischarged+Injectedwater+Exportedwater

Oilconcentration Oilconcentrationshallbereported,calibratedagainsttheISOmethod.

OiltoseafromjettingDispersedoilandoilappendageonsandshallbeanalysedaccordingtoOSPARsreferencemethod(OSPAR,2005).Oilappendageonsandshallbereportedasgoil/kgdrysand.Basedonthedischargevolumesandoilconcentrationthetotaloildischargefromjettingoperationscanbecalculated,referenceismadetochapter4inGuidelines085.




Enter data for volumes, oil analysis for all types of water, produced water jetting and analysis reporting system (Environmental

Accounting).

Perform calculations of monthly oil content. Current average for all water types. Calculation of

quantities

Inform responsible. Adjust data

Not approved

Generating EEH tables. Report to the EEH according

to EEH routines

Annualreporting to EEH. Writing comments and drawing graphs

Extraction of data from the environmental accounting system. Align

with Chapter 4 for chemicals

Perform analysis according to Norwegian standards and

internal procedures.

Generate reports (KPIs etc.)

Quality Assurance Is all drainage water included?

Also drainage water that is injected?

Is oil analysis calibrated to ISO method?

Is the development of the oil content in produced water as

expected? What causes major changes in concentrations and emissions?

Has the concentration of any dissolved components in produced water changed significantly?

Is the water coming from upstream fields included?

Is downstream field informed about the waterstream?

Are all jetting operations included? Are the results as expected? If not: Why?

+ Internal routines for quality assurance

Yearly / monthly data OK



4 USEANDDISCHARGEOFCHEMICALS


General Allchemicalsusedoffshore,andwhichrequirepermissionforuse,shallbereported.Thereportedchemicalsrequireeco‐toxicologicaldocumentationintheformofanHOCNF,andtheoperatorshallensurethatchemicalsused,re‐injectedordischarged,aretestedforeco‐toxicologicalproperties.Ref“Aktivitetsforskriften”§62to§67.Thechaptershallprovideanoverviewofconsumption,dischargesandinjectionofchemicalsinthefield.Theconsumptionofchemicals,injectionandemissionsshouldbegivenintonnesperareaofuseandfunctiongroup.Specificchangescomparedtolastyear,forexamplenewareasofapplication,majorchangesinconsumptionand/ordischarges,shallbecommentedoninthetext.Theuncertaintyoftheindividualemissionsshouldbebrieflyexplained.Accidentalspillsofchemicalsmustbereportedinchapter8.Ageneralconsiderationforreportingofchemicals(Chapter4,5and6),istheimportanceofconsistencybetweenthenumericalvaluesinthevariouschapters.Dischargesspecifiedinchapter4shallhavethesamenumericalvalueasthetableinchapter5.Thereportingrequirementappliestoallchemicalsusedfordrilling,welloperations,process,utilitysystems,andrelatedoperationsofthefacilities.Thechemicalsaredividedintoareasofapplication.

Chemicalisthecommontermforchemicalsubstancesand/orpreparations. Substancesarethechemicalingredientstheproductcontains.Asubstancecaninmanycasesbeapure

chemicalcompound,butitcanalsobeadistillateoranothercomplexcompound(physicalmixture).Thesubstancemustbeindicatedwithauniquechemicalcomposition.

Productisthenameofthechemicalproductused.Theproductisoftencomposedofsubstancesconsistingofoneormoreactivesubstances,withanorganicoraqueoussolventaddedtoit.

Tradenameisthenamethattheproductissoldas.Aproductcanhaveseveraltradenamesdependingonthesupplier.

Areasofapplicationtellwhatareasthematerialisused;asforexampledrilling,production,gasprocessing,etc.

Functionalgroupsaredividedaccordingtothefunctionthechemicalhas;asforexamplecorrosioninhibition,defoaming,etc.Thefunctiongroupsarecommontoallareasofapplication.

ThePlonorlistisalistfromOSPARofchemicalsthatisassumedtohavelittleornoeffectonthemarineenvironment.

NemsChemicalsisadatabasewithHOCNFinformation.Dischargeofchemicalsisquantifiedbymassbalanceprinciple.Forproductionchemicalsandchemicalsfromotherproductionsites,thedischargeamountwillbedeterminedbymassbalancebasedonaddedamounts,injectionpoint,solubilitypropertiesinwaterandthedistributionofproducedwaterbetweendischarge,exportandinjection.Productsaddedtotheproductionstreamwillfollowtheoilorwater.Water‐solubleproducts/substanceswillmainlyfollowtheproducedwaterwhichisdischargedorinjected.Commentsshouldbeaddediftherearechangescomparedtolastyear'sreport,suchasinformationaboutchemicalssolubilityproperties.



ForchemicalsinapplicationareaGandHtheinterfaceswithotherfieldsandcooperationwithotherOperatorsshallbedescribed,whereapplicable.Itshallbeindicatedwhethertheproductstreamreceivedfromotherfieldscontainchemicals(thisappliesforchemicalsinapplicationH),andifinformationonthisisreceivedfromtheOperatoroftheupstreamfield.Similarly,itshallbeinformedifanexportstreamcontainschemicalsandiftheOperatorsofthedownstreamfacilitieshavebeeninformedaboutthis.Thetotalproductamountshallbereported,alsotheamountofwaterinthechemicalproduct.Amountofwaterisindicatedasaseparatesubstanceonparwithothersubstances.Thechemicalsshouldbeplacedinfunctionalgroupsbasedonthefunctiontheyhave.Thismeansthat:

FunctionGroup26,completionchemicals,shallonlybeusedforthosechemicalsthatarespecificallyusedforcompletion.Otherchemicalsusedduringthecompletionoperation,suchasbarite,shallbeplacedunderthefunctionalgroupstheynaturallybelongto(bariteingroup16,etc.)

FunctionGroup10,hydraulicfluid,shallonlybeusedforcleanhydraulicfluid.Anyadditivesareplacedundertheirrespectivefunctionalgroups(e.g.CorrosionInhibitoringroup2).FunctionGroup10alsoincludeshydraulicfluidsthattraditionallyhavehadaseparatefunctiongroup,e.g.BOPfluid.

Withineachapplicationareainformationaboutallproducts(tradename)usedshallbereported.Drillingandwellchemicalsaretobereportedatwellborelevelforeachinstallationinwhichtheyareused.Otherchemicalsarereportedatfacilitylevel.ForthereportingofchemicalsotherthandrillingandwellchemicalstoEEH,itshouldbereportedblankinthecolumn"Wellbore".ForchemicalsinfunctiongroupK(traceelements)wellborecanbereportedinthecolumn‘Wellbore’.Use,dischargeandinjectionofchemicalsshallincludewater.

IfseveralOperatorsusethesameriginayear,theOperatorsmustagreeonhowthisshouldbereportedtoavoiddoublereporting.Useandemissionsofdispersantsandbeach‐cleaningagentstocombatacutepollution,chemicalsthataretestedonfieldandcontingencychemicals,shouldalsobereported.

Exceptions Thefollowingchemicalsareomittedfromthereportingrequirement:

Chemicalsthatarereleasedfromthesacrificialanodes,ship‐bottompaint(bunnstoff)etc. Hypochloriteandcopperfrom"electrochlorination" "Watermakers",i.e.chemicalsusedintheproductionofdrinkingwater/freshwaterandthereforehave

approvalfromhealthauthorities

ApplicationareaA–Drillingandwellchemicals Definition:

Drillingandwellchemicalsarechemicalsthatareusedforwellactivitiesandareeitherinjected,dischargedtosea,losttotheformationorsenttoshore.Theseincludechemicalsusedfor:

o DrillingOperations

ChemicalsinclosedsystemsGuidelinesfromNorwegianEnvironmentAgencystatesthat"Allconsumptionanddischargesofchemicalsshallbereported,includingconsumptionofchemicalsinclosedsystemwithaconsumptionofmorethan3000kgperfacilityperyear".ChemicalsinclosedsystemsshallbereportedundercategoryF.



o WellCompletion o Wellworkover(wireline),wellclean‐upandwellmaintenance o Cementing o WellStimulation

Allchemicalsusedinthedrillingmodule(suchashydraulicfluids,lubricantsanddope)shallbereportedhere.

Chemicalsaddedtowellstomaintain/improveproductioncharacteristics(suchasacid‐stimulatingchemicals,scaleinhibitorsandscaledissolvers)areperceivedaswelltreatmentchemicalsandshallbereportedhere.

Dieselusedforwelltreatmentshallalsobereportedhere. Drillingandwellchemicalsshallbereportedatwellborelevel.

ApplicationareaB‐ProductionChemicalsDefinition:

Chemicalsaddedtotheproductionstreamwithanintenttoinfluence/helptheproductionprocessatthefacility.

Chemicalsaddedtosatellitefieldsandtransportedbypipelinetothemainfieldwiththesamepurpose. Chemicalsthatareinjectedtoincreasetheproduction

Exception:

ChemicalsusedfordehydrationorCO2andH2Sremovalfromnaturalgas(ApplicationareaE‐GasTreatmentChemicals).

Chemicalsfromotherproductionsites(ApplicationareaH‐Chemicalsfromotherproductionsites)

ApplicationareaC‐InjectionChemicalsChemicalsaddedtoliquidorgasandinjectedintotheformationtoincreaseproductionofoiland/orgasthatcanbeback‐producedinproductionwells:

Injectedseawater/sourcewater:Allchemicalsaddedtoseawater/sourcewaterbeforeinjection. Producedwatertobeinjected:Chemicalsaddedonlyforinjectionpurposes,i.e.aftertheoutletofoil/

gas/waterseparator. Otherchemicalswhichareinjectedintothereservoirforproductionofoilandgas,forexampleby

secondaryandtertiaryrecovery,gelstostopthewaterrise,etc. WaterInjectionChemicalsusedinsatellitefieldandwhicharecomingbackwiththewellstreamand

pipelinetothemainfield.

ApplicationareaD‐PipelineChemicalsDefinition:

Chemicalsusedwhenlaying,preparing,anddraining,startup,andshutdownofpipelines Coloursubstances

ApplicationareaE–GasTreatmentChemicalsDefinition:

ChemicalsusedfordehydrationofnaturalgasortheremovalofCO2and/orH2Sfromnaturalgas. Exception:

Chemicalsinjectedintothepipelineforcontrolofhydrate(includedintheApplicationareaG‐Chemicalsaddedexportflow)



ApplicationareaF‐UtilityChemicalsDefinition:

Chemicalsusedinutilityprocessesontheplatform o Coolingsystems o Detergents o BOPfluids o CorrosionInhibitors o Firefightingchemicals,alsowhenusedintestsandduringverification o Etc.

Chemicalsusedforwashingandcleaningoperationsofthefacilitiesanddischargedthroughthefacilitydrainagesystems.

Theuseanddischargeofgreaseforjack‐upoperationsshallbereported. Chemicalsinclosedsystemwithconsumptionofmorethan3000kgperreportingentityperyear. AsperM107‐2014,theEnvironmentAgencywouldlikefire‐fightingchemicals,includingthoseused

duringexercisesandtesting,tobereportedinEEH.Previously,onlyusewasspecifiedinthetext.

ApplicationareaG–ChemicalsaddedtotheexportstreamDefinition:Thesearechemicalsthatareaddedinpipelinesystemstoperformfunctionsinthetransportsystem,suchas:

Inhibitorstoavoidhydrates Friction‐reducingadditives("Dragreducers") Corrosioninhibitorsandbiocides Chemicalsinotherwatervolumesthatareaddedtotheexportflow

Exception:

Productionchemicalsthatfollowtheexportstream. Chemicalsaddedtoflowlinesatsatellitefieldsandtransportedbythewellstreamtothemainfield

(reportedinApplicationareaB‐ProductionChemicals). IfchemicalsinApplicationareaGisused,thedownstreamoperatormustbeinformed.Exportstreamswillalsocontaintheflowofresidualwaterproducedsinceonshoreprocessingplantsallowsupto0.5%watercontentintheoil.Itmaythereforebenecessarytoinformtheonshorereceivingfacilitiesaboutthechemicalcontentintheexportstream.Normallytherewillbenodischargeofchemicalswithinthisrangeofuse.Dischargewillhoweverbepossibleatthedownstreamfacility.ThesedischargesshallbereportedunderApplicationHbythedownstreamfields.(Consumption,however,shallbereportedunderApplicationGbytheupstreamfacility).Note!ItisimportantthatthisinformationisreportedandthatallreportsareforwardedtothedownstreamOperator.Thedownstreamoperatorscanthenincludethisinformationintheirreport(inApplicationareaH).

ApplicationareaH–ChemicalsfromotherproductionsitesDefinition:

ThesearechemicalsthatarereportedasconsumptioninApplicationareaGattheupstreaminstallation. Itisnotnormallyreportedconsumptionunderthisrangeofuse.Consumptionshallbereportedbythe

upstreamoperatorunderApplicationG;dischargemayhoweveroccur. Exception:

Chemicalscomingfromthewellheadplatformandsubseafacilitiesviaflowlinesshallbereportedasproductionchemicals.

InformationaboutthechemicalsinapplicationareaHmustbeobtainedfromtheoperatoroftheupstreamfacilities.Thereportshalldescribetheinterfacewiththeupstreamfacilitiesandhowcoordinationwiththeupstreamoperatorhastakenplace.



ApplicationareaK–TraceelementsDefinition:

Heretraceelementsortracersmeansoil‐andwater‐solublesubstanceswhichareinjectedintothewellstoimprovereservoircontrol

Exception:

Gastracersaretobereportedinsection7.4 Consumption,dischargesandanyinjectionoftracersshallbegiveninkg.


Table12EEHinputtable:ChemicalProduct

Column Normal Value / Comments Operator The name of the Operator StructureType ChemicalProduct ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location

Wellbore If the use of chemicals can be allocated to a particular well this should be stated. If not, the facility name as given in the column "Facility" shall be used.

RangeOfUse Write the character code of the range of use where the chemical is used. See Table 13 for a summary.

FunctionGroup

Write the number code for the function the chemical has. See Table 14 Functional groups for chemical reporting for a summary.

TradeName Trade name of the substance Supplier Chemical Supplier

ColourClassification The product colour code. The same as the product's most hazardous substance. Given as Black, Red, Yellow or Green.

Used (tonnes) The consumption of the product in the reporting year Discharged (tonnes) The discharge of the product in the reporting year Injected (tonnes) Injected amounts of product in the reporting year

Contingency Indicates whether the substance is used as an emergency chemical or not. Yes/No.*

*Note that function group 28 (Firefighting chemicals (AFFF)) are contingency chemicals regardless of use. Table13Rangeofuseforchemicalreporting

Application Operations A Drilling and well treatment chemicals B Production chemicals C Injection chemicals D Pipeline chemicals E Gas treatment chemicals F Utility chemicals G Chemicals added to the export stream H Chemicals from other production sites K Chemicals for reservoir management




Table14Functionalgroupsforchemicalreporting

No. Function 1 Biocides 2 Corrosion Inhibitor 3 Scale Inhibitor 4 Antifoam 5 Oxygen Remover 6 Flocculent 7 Hydrate inhibitor 8 Gas Drying Chemicals 9 Antifreeze 10 Hydraulic fluid (including BOP fluid) 11 PH-regulating chemicals 12 Friction-reducing chemicals 13 Wax inhibitor 14 Dye/colorant 15 Emulsion breaker 16 Weighting materials and inorganic chemicals 17 Chemicals to prevent lost circulation 18 Viscosity-changing chemicals (including lignosulfate, lignite) 19 Dispersants 20 Surfactants 21 Shale Stabilizer 22 Emulsifier 23 Dope 24 Lubricants 25 Cementing Chemicals 26 Completion Chemicals 27 Washing and cleaning products 28 Firefighting chemicals 29 Oil-based base fluid 30 Ester-based base fluid 31 Polyalphaolefin-based base fluid 32 Water Treatment Chemicals 33 H2S scavenger 34 Diversion agent 35 Chlorine remover 36 CO2 remover 37 Other 38 Scale remover 39 Beach-cleaning agents




Calculationofdischargesandre‐injectionofchemicalsinApplicationAThefateofchemicalsusedindrillingandwelltreatmentisoftendifficulttodetermine.DrillingOperatorwillineachcaseassesshowmuchofthechemicalsareleft/lostinthewell,dischargedorreturnedforreinjection.Duringwelltreatmentoperationswherechemicalsareaddedtothewell,butwheretheseareexpectedtoberecovered/back‐producedovertime,shouldchemicalsdischargedbereportedbasedonthesolubilityinanddensityofthewaterflow,basedontheprinciplesinchapter4.3.2.

Calculationofemissionsandre‐injectionofchemicalsfromapplicationareaBandHThesechemicalsareaddedtotheproductionstreamandwillfollowtheproductionstream.Eachchemicalmustbeevaluatedforsolubilityinwater.Someoperatorsconsidereachsubstanceineachchemicalfortheirspecificsolubilityinwater.Theproportionofthechemicaldissolvedinoilwillfollowtheproductionstreamandnotbedischarged.Theproportionofthechemicalthatdissolvesinwaterwillfollowthewaterstream.Onecanthusformulatethefollowingbalance:

kOkk

total

ortedkVkk

total

emissionkVkk

total

injectedkVkk

kkkkk

aFO

PV

PVaFE

PV

PVaFU

PV

PVaFI

OEUIF

*

**

**

**

exp

Table15Explanationofthecomponentsinequation(2)

Component Explanation Fk Consumption of chemical k Ik Injected amount of chemical k Uk Discharged amount of chemical k Ek Exported amount of chemical k Ok Amount of chemicals k dissolved in the oil phase akO The proportion of chemical k which is dissolved in the oil phase akV The proportion of chemical k which is dissolved in the water phase PVTotal Total produced water volume (including produced water from upstream facilities) PVInjected Produced water injected PVEmissions Produced water discharged to sea PVExporterd Produced water exported to downstream field

Total

injectedkV PV

PVa *

This part of the equation gives the proportion of chemical k injected

Total

emissionkV PV

PVa *

This part of the equation gives the proportion of chemical k discharged

total

exsportedkV PV

PVa *

This part of the equation gives the proportion of chemical k exported with the produced water. Downstream fields shall be informed, and the chemicals shall be reported as chemicals from other production sites (preparation H) by the downstream fields.




Enter data for consumption, emissions and re-injection of chemicals into the reporting system (Environmental

accounting).

Make estimates of oil and water distribution of chemicals, as well as re-injected amounts

Notify administrators.

Adjust data

Not approved

Generating EEH tables. Report to the EEH according to EEH

routines

Annual reporting to EEH. Writing comments and graphing

Extraction of data from environmental accounting system.

Make oil and water distribution in the substance level and / or product level

Generate monitoring

reports (KPI)

Follow-up of the phase-out plans

Quality Assurance Is the latest version of HOCNF MSDS available for all chemicals?

Does chemical consumption comply with purchased chemicals?

Is there a mass balance for all chemicals?

Are chemicals from upstream fields included? Are the downstream fields informed about accompanying chemicals?

Is the distribution of chemicals for injection and discharge, the same as the total use of chemicals?

Have there been specific events / process changes that have led to changes in chemical use?

Is the chemical use in accordance with the previous years’ consumption?

Is the chemical use in accordance with the drilling activity?

Are phase-out plans followed?


Annual / monthly data OK



5 EVALUATIONOFCHEMICALS


Thischaptershallprovideanoverviewofthechemicalsaccordingtothechemicals’environmentalproperties.ThecurrentcriteriaaregivenbyNorwegianEnvironmentAgencyinM107‐2016Retningslinjerforrapporteringfrapetroleumsvirksomhettilhavs,Chapter5(inNorwegianonly).Theevaluationistobedoneonsubstancelevel.Substanceisinthiscontextdefinedastheindividualcomponentsofeachchemicalproduct.Table16Evaluationcriteriaandcategoriesforevaluationoftheenvironmentalpropertiesofsubstancesinchemicals

Emissions

Category1 Norwegian Environment Agency’s color- category

WATER 200 Green Substances on the PLONOR list 201 Green Substance covered by REACH Annex IV2 204 Green Substance covered by REACH Annex V3 205 Green Substances missing test data 0 Black Additive packages that are exempted from test requirement and not tested

0.1 Black

Substances that are believed to be or are harmful in a mutagenic or reproductive manner4 1.1

Black

Substance on the list of priority chemicals or on OSPARS priority list7 2 Black Substance on REACH candidate list8 2.1 Black

Biodegradability <20% and log Pow ≥ 55 3 Black

Biodegradability <20% and toxicity EC50 or LC50 ≤ 10 mg/l 4 Black Two of three categories: Biodegradability <60%, log Pow ≥ 3, EC50 or LC50 ≤ 10 mg/l5

6 Red

Inorganic and EC50 or LC50 ≤ 1 mg/l 7 Red

Biodegradability <20% 4 8 Red

Polymers that are exempted from test requirement and not tested9 9 Red

Potassium hydroxide, sodium hydroxide, hydrochloric acid, sulfuric acid, nitric acid and phosphoric acid

104 Yellow

Substance with biodegradation> 60% 100 Yellow

Substance with biodegradability 20% - 60%

Subcategory 1 - expected to complete biodegrade.

101Yellow

Subcategory 2 - expected to biodegrade to substances that are not hazardous

102

Yellow

Subcategory 3 - expected to biodegrade to substances that may be hazardous

103

Yellow

Sum 10 1DescriptionofthecategoryisgivenintheflowchartinFigure1.CategoryinEEHTable5.1relatestothecategoryinEEHTable6.1toensurecompliancewiththefiguresreportedinthetwotables.2“Kommisjonsforordningnr.987/2008”.3NorwegianEnvironmentAgencymustconsiderwhetherthesubstanceiscoveredbyAnnexV.4Withmutagenicandreproductiveharmfulsubstancesmeansmutagenic(Mut)1Aand1Bandtoxicfor



reproduction(Rep)1Aand1B,cf.appendix1inforskriftomklassifisering,merkingmv.avfarligekjemikalierellerselvklassifisering».5Datafordegradabilityandbioaccumulationshallbeinaccordancewithapprovedtestsforoffshorechemicals.6Theprioritylistcanbefoundatmiljostatus.no/prioritetslisten7 OSPARListofChemicalsforPriorityAction(Revised2013)(Referencenumber2004‐12).Thelistcanbefoundhere:http://www.ospar.org/work‐areas/hasec/chemicals/priority‐action.8Substancesonthecandidatelistcanbefoundhere:http://www.echa.europa.eu/candidate‐list‐table9Jf.Aktivitetsforskriften§§62‐63.10"Sum"shouldmatchthenumberofchemicalspillsreportedinchapter4. ReportedconsumptionanddischargeamountsinChapter5shouldmatchtheamountsreportedasconsumptionanddischargeinchapter4.Ifdischargesofredorblackchemicalsarereportedanexplanationofthedischargeshallbereportedandthereportshallhaveareferencetoavaliddischargepermit.Theuseofredandblackchemicalsshallbeaccompaniedbyabindingsubstitutionplan.Amountofsubstancedischargedcanbecalculatedbasedontheamountofproductdischargedandtheweightpercentagesubstanceintheproduct(averageofupperandlowerlimitsusedifonlyapproximateconcentrationspecifiedbysupplier).Thepercentageofsubstancesintheproductmustbenormalisedsothatthesumofthesubstancesinaproductis100%.Thereportshallincludeafigureshowinghistoricaltrendanddistributionofthetotaldischargesforthedifferentcolourcategoriesuptoandincludingthereportingyear.Thecategoriesoverlapforsomesubstances.Thechemicalsshallonlybereportedinonecategoryandthestrictestcategoryshallbeused.ForsubstancesnotcategorizedasgreenoryellowthefollowingflowchartinFigure1isused(highestpriorityfirstcategory).Forchemicalsincategory1.1itshallbrieflybestatedwhetherthesubstanceisCategorymut1Aand1Borrep1Aand1B.



Figure1Flowchartforclassificationofchemicalsinthegroupof0.1to9

Substance on the list of priority chemicals or on OSPARS priority list

Bio degradability <20% and log Pow ≥ 5

Bio degradability <20% and toxicity EC50 or LC50 ≤ 10 mg / l

Bio degradability <60%, log Pow ≥ 3, EC50, LC50 ≤ 10 mg / l, (2 of 3)

Inorganic and EC50 or LC50 ≤ 1 mg / l

Bio degradability <20%

Reported in category 2






No

No

No

No

No

No

Genes or reproductive harmful (Mut 1‐2 / Rep 1‐2) Reported in category 1.1

No

Additive packages that are exempted from test requirement and not tested Reported in category 0.1 Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes


Polymers that are not tested

Reported in category 2.1 Substance on REACH candidate list

No

No

Yes

Yes




Table17EEHinputtable:ChemicalComponent

Column Normal Value / Content Operator Name of the operating company StructureType ChemicalComponent ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Wellbore If the use of chemicals can be allocated to a particular well this shall be stated. If

not, the facility name as given in the column "Facility" shall be used. RangeOfUse Write the character code of the range of use where the chemical is used. See

Table 13 for a summary. FunctionGroup Write the number code for the function the chemical has. See Table 14 Functional

groups for chemical reporting for a summary

TradeName Trade name of the product Used (tonnes) The consumption of the product in the reporting year Discharged (tonnes) The discharge of the product during the reporting year EnvironmentalCategory The product colour code, ref.Table 16. Component The name of the substance in the chemical Casno CAS number of the substance to ensure unambiguous identification Toxicity The substance toxicity as given in HOCNF datasheets LogPOW Enter the substance bioaccumulation potential as given in HOCNF datasheets BOD Enter the substance biodegradability as given in HOCNF datasheets Inorganic OnListOfPrioritySubstances List of priority substances





Table18Informationoncalculationofsubstances’environmentalcharacteristicsforreporting

Column Normal Value / Content Used (tonnes) Substance consumption in the reporting year multiplied by the substance

normalized average concentration. Normalized average concentration can be found in NEMS Chemicals, or may be calculated from HOCNF data sheet

Discharge (tonnes) Substance discharge in the reporting year multiplied by the substance normalized average concentration. Normalized average concentration can be found in NEMS Chemicals, or may be calculated from HOCNF data sheet

Component Substance name. Can be found in HOCNF data sheet and in NEMS Chemicals Toxicity The substance’s toxicity. Can be found in HOCNF data sheet and in NEMS

Chemicals. Used to decide Norwegian Environment Agency category. LogPow The substance’s bioaccumulation potential. Can be found in HOCNF data sheet

and in NEMS Chemicals. Used to decide Norwegian Environment Agency category.

BOD The substance’s biodegradation potential. Can be found in HOCNF data sheet and in NEMS Chemicals. Used to decide Norwegian Environment Agency category.

EnvironmentalCategory All substance shall be allocated to a Norwegian Environment Agency class. Ref. Table 16. They shall be allocated based on the substance’s environmental toxicity. Each substance’s toxicity, bioaccumulation and biodegradation potential shall be evaluated. The substance shall be allocated to the strictest applicable category in Table 16. No substance shall be double reported. In class 201 – PLONOR, only data that is on OSPARS PLONOR list should be reported.




Ikke godkjent

Obtain eco toxicological data on substance levels from HOCNF data sheets or from Nems Chemicals®.

Notify administrator.

Adjust data

Compare with the discharge permit

Annual reporting to EEH. Writing comments and adding graphs

Extraction of data from environmental accounting.

Generate monitoring reports

(KPI)

Allocate all components according to evaluation criteria

Perform calculations of fuel consumption and emissions of each evaluation criteria, per application and total

Approved

Extraction of data from the environmental accounting system.

Submit an application to the Norwegian Environment Agency for permission. Register deviation in internal system

Deviation

Continuous process

Annual process

Quality Assurance Is the latest version of HOCNF

datasheets used? Are all substances correctly stated and

named?

Do the figures correspond with the previous years’ emissions, in the

context of use of chemicals?

Are all substances that are reported as PLONOR on the PLONOR list?

Are the numbers the same as in chapter 4?

Is consumption of red and black chemicals justified?

Does chemical use follow the discharge permit?


Not approved

Consumption, emissions and injection of chemicals, retrieved from chapter 4



6 USEANDDISCHARGEOFHAZARDOUSSUBSTANCE

Chemicalsthatcontainhazardoussubstances

Thereportinginsection6.1willcontainconfidentialinformationandshallnotbeincludedintheannualreport,butisreportedtotheNorwegianEnvironmentAgencyonlyasdatauploadedtoEEH.Itshouldbenotedthatchemicalsusedduringthereportingyearshallbereported,eventhoughnodischargeduringthereportingyearhasoccurred.Similarly,forchemicalsusedandreportedasusedpreviousyears,theseshallonlybereportedasdischargediftheyweredischargedinthereportingyear.ChemicalsthatareonthePLONORlistshallnotbereported,althoughtheyfulfilltherequirementsforBOD<20%(e.g.cellulose).Somesubstancescanoccurinseveralproducts.Ifthesearesuppliedbydifferentmanufacturers/suppliers,thetestdatamightvary.Itisrecommendedtoreportstrictandaccordingtotheformat.Thismeansthatthesamesubstancecanbeenteredmultipletimeswithdifferentdataforbioaccumulationpotentialanddegradability.

CompoundsonthePriorityList,asadditivesandcontaminantsinproductsAcombinedoverviewofthedischargesofcompoundsthatareonthelistofprioritysubstances4,shallbegiven.Compoundspresentasadditivesandcontaminantsinchemicalproductsshallbereported.TheinformationshallappearintheHOCNFdatasheet.Usenormalizedcutforcalculatingdischargesifthecontentoftheadditiveisreportedasaconcentrationrange,e.g.0.1‐0.3weightpercentoftheproduct.Earlierthiswasreportedin9maingroups,nowthepollutantsonthelistofprioritysubstancesaretobereportedseparately. Table19Thepollutantsonthelistofprioritysubstances

Pollutants on the list of priority substances Arsenic Bisphenol A Lead Brominated flame retardants Decamethylcyclopentasiloxane Diethylhexylphthalate 1,2 dichloroethane (EDC) Dioxins (PCDD/PCDF) Dodecylphenol Hexachlorobenzene (HCB) Cadmium (Cd) Chlorinated alkylbenzenes (KAB) Chlorinated paraffin short chained (SCCP) Chlorinated paraffin medium chained (MCCP) Chromium (Cr) Mercury (Hg) Muskxylene Nonyl- og octylphenol Octamethylcyclotetrasiloxane (D4)

4http://www.miljostatus.no/Tema/Kjemikalier/Kjemikalielister/Prioritetslisten/



Pollutants on the list of priority substances Pentachlorophenol PAH PCB PFOA PFOS C9-C14 PFCA’er Surfactants Tetrachlorethylene (PER) TBT og TFT Trichlorobenzene (TCB) Trichloroethene (TRI) Triclosan Tris (2-chloroethyl) phosphate (TCEP) 2,4,6 tri-tert-butylphenol (TTB-phenol) Twotablesshallbeprepared,oneforadditivesinproductsandoneforpollutioninproducts.CalculationofdischargesinEEHTable6.3shallbebasedonconcentrationsgivenintheHOCNFdatasheet.Iftheproductsarespecifiedtocontaintrace(<100ppm)ofthecomponent,50ppmisusedforcalculatingtheamount.ThereshallbeabriefexplanationofthefiguresinTableEEH6.3.Thismeansthatitshouldbeclarifiedwhetherthereportedheavymetalspollutionisfromweightmaterialetc.

ReportingTablesinEEH

Table20EEHinputtable:ChemicalContaminant

Column Title Normal Value / Content Operator Name of the operating company StructureType ChemicalContaminant ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Wellbore If the use of chemicals can be allocated to a specific well, it shall be mentioned.

If not, it should be reported blank in Wellbore. RangeOfUse Write the character code of the range of use where the chemical is used. See

Table 13 for a summary. FunctionGroup Write the number code for the function the chemical has. See Table 14

Functional groups for chemical reporting for a summary

TradeName The trade name for the chemical Component The name on the compound ContaminantType Indicate whether the compound is: Additive or Contamination ComponentContaminantGroup Specify the component on the priority list, ref. table 19. Discharged (tonnes) The amount of the discharge for the specific compound





DischargesarecalculatedbyobtainingthecompoundconcentrationfromHOCNFdatasheetandmultiplythecompoundconcentrationintheproductwiththeamountofproductdischarged.Usenormalizedcutforcalculatingdischargesifthecontentoftheadditiveisreportedasaconcentrationrange,e.g.0.1‐0.3weightpercentoftheproduct.


Retrieving chemicals data from environmental accounting (Chapter 4)

Obtaining information on additives and contaminants in chemicals from HOCNF data

sheets or from Nems Chemicals®.

Notify administrator.

Adjust data

Not approved



Allocate additives and contaminants on the right type and group

Perform calculations of emissions of each pollutant or added component, per application and

total

Approved

Quality Assurance Is the latest version of HOCNF

datasheets used? Do the figures Correspond with

earlier years of release, in conjunction with the use of

chemical’s?

Are all additives and contaminants included?




7 EMISSIONSTOAIR


Forfieldlocatedatthebordertoothercountriescontinentalshelf,theemissionsshallbereportedastheactualemissionsfromfacilitieslocatedontheNorwegiancontinentalshelf(geographicalsplit).EmissionsfromintermediatecompressorstationsandNorwegianreceiverterminalsofthepipelinesystemshouldalsobereported.Emissionsfromallfixedinstallationsandmobileunitsshallbereported.Thisincludesmobileunits,connectedtoapermanentfacilitywithabridge.Emissionsfromexplorationactivityshouldbereportedusingthesametemplate,butinaseparatereport.FactorsusedtocalculateemissionsmustbegivenpersourceaccordingtoM‐107.ThesefactorswillbebackcalculatedpersourceinEEHandareavailablethere.Thisoccurswithouttheoperatorshavingtodoanything.Emissionsthataresubjecttoquotasshouldmatchthenumbersreportedinquotacontext.Anydeviationsmustbeexplained.Theuncertaintyoftheindividualemissionsshouldbebrieflyexplained.

CombustionsourcesCombustiongasesaregasesfromthecombustionprocessesthattakeplaceinconnectionwiththepetroleumactivity.Hydrocarbonliquidsorgasesareusedasfuel.Emissionsvarywithfueltypeandcombustionprocess.Combustionofhydrocarbonsiscarriedoutduetothefollowingpurposes:

Energyconversion Flaring Burningofoilandgasinconnectionwithwelltestingandwellclean‐up.

NotethatincasesofdirectemissionsofCO2,thisshouldbereportedunder‘othersources’.

CombustionofgasFuelgasisusedforgasturbines,direct‐firedboilersandgasengines.NorwegianOilandGasAssociationhasnotgivenrecommendationonemissionfactorsfordirect‐firedboilersandgasengines.Theoperatormustobtaintheappropriate/representativeemissionfactorsfrommeasurements,calculationorestimation,andobtainanapprovaloftheemissionfactorsbyNPD/NorwegianEnvironmentAgency.Quantificationoftheemissionsismadeontheequipmentlevel.“Forskriftomsæravgifter”listssjablonvaluesforNOxemissionfactors.Duetothedifferencesinemissionfactorsfordifferentequipmenttheoperatormustdeterminetheamountoffuelgasthatgoestotheindividualsubsystems(turbines,boilers,engines)andonequipmentthathavedifferentemissionfactors.Thiscanbedonebyinstallingseparategaugesoneachsubsystem,orbycalculatingthedistributionoffuelgasinthesubsystemsbasedonenergydemand.Measuredfuelgasmightbeusedforotherpurposes,andeventuallypartofthegasmightbesenttoflareorventedtocoldvent,insteadofcombustionasfuelinenergyconvertingequipment.Ifthatisthecaseitshouldbeassuredthatthesegasquantitiesarenotreportedtwice(e.g.thefuelgasismeasuredinthecombustiongasmetreaswellasflaregas,whenthegasalsorunsthroughtheflaregasmetre).



CombustionofdieselDieselisalsousedforpurposesotherthanfuel.Dieselforsuchpurposesmustbedeductedfromthetotalamountofdieselusedonthefacilitybeforeemissioncalculations,unlessthequotapermitstatesotherwise.Mobilefacilitiesusenormallydieselasfuelfordieselengines,andinsomecasesindiesel‐firedboilers.Atfixedinstallationsdieselarealsousedin"dualfuel"gasturbines,e.g.whengasproductionstopsorirregularitiesinthegascompressionoccur.Itisimportantthattheconsumptionoffueltypeforeachofthesesubsystemsisdetermined,sinceemissionsfactorsforNOx,nmVOCandCH4aredifferentfordifferentequipment.Theemissionfactorswillalsovarydependingonthedensityofdieselburned.Thismustbetakenintoaccountwhencalculatingemissions.

FlareAllproductionandprocessingplatformsareequippedwithflaretowerandshallreportflaringofgas.Flareisusedtoevacuateorreleasepressurefromtheprocessequipment,topreventcriticalsituations.Unlesstheinstallationhasinstalledequipmentforclosedflareapilotflamemustalwaysbeburning.Flaringaccountsforabout10%ofCO2emissionsfromtheNorwegianpetroleumindustry.Theflaregascompositionmaydifferfromthefuelgascompositionandshallbereportedseparatelyfromfuelgasusedforpowergeneration.Iffield‐specificemissionfactorsarenotavailable,andpermissionisgiven,therecommendedemissionfactorsforcalculationcanbeused.SeeSection7.1.9EmissionFactors.TheemissionfactorsforNOx,CH4andnmVOCmayvarywiththeamountofgasflared.Since2007astandardNOxfactorof1.4gNOx/Sm3gasflaredhasbeenusedforflaring.

WelltestBurnedoil,gasanddieselshallbestated.Thisincludesdieselusedtobalancethewellatthestartofawelltest.Typicalemissionfactorusedtocalculatespilledoilintotheseawhenflaringbyusingboomfromwelltestingandwellclean‐upis0.05%.BurningoilanddieselduringwelltestwillresultsinemissionsofPCB,DioxinsandPAH.TheseshallbereportedinaccordancewithemissionsfactorsgiveninTable23and



Table 24.

Welltestingisdividedintothefollowingsources:

Welltest Wellcleanup Bleedoverburnerboom

EmissionsfromstorageandloadingofoilThischapterappliestoemissionsofhydrocarbonsintotheairfromfieldswhichuseoffshoreloadingofcrudeoil.Emissionsoccurbothduringloadingofcrudeoiltoshuttletankersandfromstorage‐orproductionvesselsasaresultofstorageofcrudeoil.TheemissionsconsistofCH4andnmVOCmixedwithinertgas.OnlyCH4andnmVOCaretobereported.ThereportingshallbecoordinatedwiththereportoftheVOCindustrialcooperation.

DirectemissionsofmethaneandNMVOCThisisdirectemissionsofnaturalgasfromprocessequipmentattheoilandgasfacilities.Emissionscancomefromallsystemshandlinghydrocarbons.Emissionsarehydrocarbongaseswhicharedividedintomethane(CH4)andnmVOC.Emissionsourcescancomefrom:

ColdVent.Theseareemissionsthataretakenintoaccountduringtheconstructionofthefacility.Emissionscaninmanycasesbequantifiedbycalculationsbasedonthedesignandmanufacturingdata.Coldventilationcantakeplacethroughcommonemissionchimneysoremissionpointsintheproductionequipment.

Smallleakagesintheprocess.Theseareemissionsthatarereferredtoas‘diffuseemissions’andcomefrompumps,flangesandvalves.Theseemissionscanbedifficulttoquantify.

Fromthedischargeyear2017,therearenewrequirementsforreportingdirectemissionsofmethaneandNMVOC.Possiblesourcesofdirectemissionsaregiveninthetablebelow.Allsourcesmustbereported,includingsourcesthatarenotontheinstallation.Thesearelabeled'Notoninstallation'inthecolumn‘Fate’.Fortheothersourcesthefateshallbegiven:

Commonmeasuredvent Localvent Senttoflare Recycled

Ifthewastegasissenttodischarge,theamountdischargedshallbereported.ThisshallbecalculatedandreportedasspecifiedinAppendixB(onlyavailableinNorwegian).Recommendedquantificationmethodsareavailableformostemissionsources.Forsomesources,itisrecommendedthattheoperatorsestablishtheirownfacility‐specificmethods.Operatorsshall,intheiremissionsreporting,indicatethemethodusedforquantificationforeachemissionsource.Theoperatorsmayusefacility‐specificquantificationmethodforsourceswheregeneralmethodisrecommended.Itmustthenbeprobablethatthefacility‐specificmethodgivesaspreciseorbetteremissionfiguresthanthegeneralmethod.Notethatforthesourcesthatreportedthefollowingunderfate:

Notoninstallation Burnedinflare Recycling

mustbereportedaccordinglyundermethodinEEH.Thisisbecausemethodisacompulsoryparameter.Table21providesanoverviewofthepre‐definedcalculationmethodsthatcanbeselected.



Table21–Pre‐definedcalculationmethods.

Calculation methods

Direct measurements

Indirect measurements

Mass balance

Not on installation

GRI‐GLYCalc (only for 10 and 20 series)

MultiProScale (only for 10 and 20 series)

Emission factor

1% general addition (only for 910.1)

3% general addition (only for 900.1)

Data from supplier

Henrys law (only for 40 serie)

Flare

Recycling

Included in Atmospheric common vent

Other ISM

Flowrate of stripping gas

Calculated from upstream pressure and amount of water

Registration of time with unignited flare

OGI leak/no leak

Calculation of flowrate

Annual vented storage tank volume

Volume of vented process plant

Ageneraladditionisaddedtothecalculatedemissionstoincludeemissionsfromvarioussourceswithsmallcontributions.Theoperatormustadd1%ofthesumofthecalculatedemissions(mandatory).IfthefacilityisanFPSO/FSOwithoilstorageandinertgas(neutralgas)asblanketgas(afterthelastoilloadingbeforetankinspection)thegeneraladditionisincreasedto3%.

Table22–Sourcesofdirectemissions.Source ID Main Source Sub source Fate Methodology CH4 nmVOC

tonnes tonnes

1.1 Measured emissions Atmospheric common vent

10.1 Triethyleneglycol (TEG) regeneration TEG degassing tank

10.2 Triethyleneglycol (TEG) regeneration TEG regenerator

10.3 Triethyleneglycol (TEG) regeneration Stripping gas

20.1 Monoethyleneglycol (MEG) regeneration MEG degassing tank

20.2 Monoethyleneglycol (MEG) regeneration MEG regenerator

20.3 Monoethyleneglycol (MEG) regeneration Stripping gas

30.1 Amine regeneration Amine degassing tank



30.2 Amine regeneration Amine regenerator

40.1 Produced water handling Produced water degassing tank

40.2 Produced water handling Flotation tank / CFU

40.3 Produced water handling Flotation gas

40.4 Produced water handling Discharge caisson

50.1 Centrifugal compressor sealant oil Degassing pots

50.2 Centrifugal compressor sealant oil Sealing oil retention tank

50.3 Centrifugal compressor sealant oil Sealing oil storage tank

60.1 Piston compressor Separator chamber

60.2 Piston compressor Crank shaft housing

70.1 Dry compressor seals Primary seal gas

70.2 Dry compressor seals Secondary seal gas

70.3 Dry compressor seals Leakage of primary seal gas to secondary vent

80.1 Flare gas that does not burn Extinguished flare and ignition of flare

80.2 Flare gas that does not burn Non‐flammable flare gas

80.3 Flare gas that does not burn Inert gas flushed open flare

90.1 Leaks in the process Larger gas leaks

90.2 Leaks in the process Small gas leaks

100.1 Purge and blanket gas Purge and blanket gas

110.1 Gas analysers and test stations Gas analysers and test stations

120.1 Drilling Drilling

130.1 Storage tanks for crude oil at FPSO/FSOs

Gas freeing in connection with tank inspection

130.2 Storage tanks for crude oil at FPSO/FSOs

Abnormal operating situation

140.1 Gas freeing of process systems Gas freeing of process systems

900.1 General addition FPSO/FSO

910.1 General addition Fixed facilities

LargergasleaksshallalsobereportedunderaccidentaldischargesinChapter8.

EmissionComponents CO2CO2emissionsoccurfromallcombustionprocesses.CO2emissionsareafunctionofcarbonnumberofthefuelused.Itshallbeusedfield‐specificemissionfactorsinaccordancewiththerequirementsoftheGreenhouseGasEmissionRegulationsandapprovedmonitoringprogramfortherelevantfacility/unit.Fordiesel,theemissionfactorisusually3.17kgCO2perkgdiesel.Formarinedieseloil,jetfuelandcrudeoil,thesamefactorisassumed,iftheredoesnotexistanequipment‐specificemissionfactor.NOxEmissionsofNOxoccursfromallcombustionprocesses.Nitrogenoxidesareformedthroughseveralmechanisms:

byoxidationofnitrogenboundinthefuel oxidationofnitrogeninthecombustionair



TheamountofNOxformeddependsonthecombustionprocess.Thespecificemissions(emissionsperkWhoutput)aresignificantlyhigherfordieselthanforgasturbines,boiler,gasflaringandwelltesting.NOxemissionsfromgasturbinesincreasewithincreasedload.Newcombustiontechnologyforgasturbines,whichgives80‐90%lowerNOxemissionswhenrunningatclosetofullload,hasbeenintroducedinmanyfieldsintheNorthSeaduringthepastyears(Low‐NOx,alsocalledDLEtechnology).Low‐NOxtechnologyfordieselenginesisalsounderdevelopment.Thesecanreduceemissionsbyupto50%comparedtoconventionaldieseltechnology.Evenloweremissionscanbeachievedbyusinglow‐NOxtechnologyofgasengines.NOxemissionsfromlow‐NOxdieselenginesarestillfarhigherthanfromconventionalgasturbines.Thereexistalsocatalyststhatcanreduceemissionsfromdieselandgasengineswithupto90%(SelectiveCatalyticReduction,orSCR). SOx Allgas,dieselandoilcontainssomesulfur,e.g.intheformofH2S.Emissionquantitiesaredirectlyrelatedtothesulfurcontentofthefuel.ThesulfurcontentingasontheNorwegianContinentalShelfis,withfewexceptions,verylow.EmissionsofSOxfromgasiscalculatedbasedontheH2Scontentofthegasasindicatedinppmandthesulfurcontentofdiesel/fueloilindicatedin%.SeeSection7.3.4forcalculationofSOxemissions. CH4 CH4emissionsoccurinallcombustionprocessesasnon‐combustedhydrocarbon.Theemissionsdecreasewithincreasingloadoftheinternalcombustionmachine.EmissionsofCH4fromburningdieselandotheroilsarenegligible. EmissionsofnmVOC nmVOCisanumbrellatermforallhydrocarbongasesexceptmethane.Emissionsoccurinallcombustionprocessesasnon‐combustedhydrocarbon.Emissionmechanismsareotherwiseasformethane. EmissionsofPAHs,PCBsandDioxin Thesecompoundsarecomplexaromaticsandchlorinatedorganiccompounds,whicharedetectedinemissionsfromwelltesting. Useandemissionsofgastracesubstances Withgastracersmeansgaseouschemicalsubstancesthatareinjectedintowellstoimprovereservoircontrol. EmissionsthatarenotreportedtotheNorwegianEnvironmentAgency EmissionsofCOoccurfromallcombustionprocesses.EmissionsofCOfrompetroleumactivitiesaresmallandarenotreportedintheemissionsreporttotheNorwegianEnvironmentAgency.EmissionsofN2Ooccurfromallcombustionprocesses.Theemissionsfrompetroleumactivitiesaresmallinanationalcontext.N2Oarecurrentlynotreportedintheannualreport.

EmissionfactorsTable23NorwegianOilandGasrecommendedemissionsfactorsfromcombustionprocessesusingnaturalgasasfuel.Shallonlybeusediffield‐/equipmentspecificfactorsarenotavailable.

Emissions Unit Turbine Engines Boilers Flaring Well testing CO2 Ton/1000 Sm3 Field-specific Field-specific Field-specific 3,72 2,34 NOx Ton/1000 Sm3 Field-specific* Field-specific* Field-specific 0,0014 0,012 CO Ton/1000 Sm3 0,0017 Field-specific Field-specific 0,0015 0,0015 N2O Ton/1000 Sm3 0,000019 Field-specific Field-specific 0,000020 0,000020 CH4 Ton/1000 Sm3 0,00091 Field-specific Field-specific 0,00024 0,00024 nmVOC Ton/1000 Sm3 0,00024 Field-specific Field-specific 0,00006 0,00006 SOx Ton/1000 Sm3 Field-specific Field-specific Field-specific Field-specific Field-specific



* If either measured or field-specific emission factors for NOx are available, refer to standard values given in the regulation on excise duties, FOR-2001-12-11-1451.



Table24NorwegianOilandGasrecommendedemissionfactorsfromcombustionprocesseswithdieselorotheroilasfuel.Shallonlybeusedifthefield‐/rig‐/equipmentspecificfactorsarenotavailable.

Emissions Unit Turbine Engines Boilers Well testing CO2 ton/ton 3,17 3,17 3,17 3,17 NOx* ton/ton Field-specific* 0,053*** 0,016 0,0037 CO ton/ton 0,0007 0,007 Field-specific 0,018 N2O ton/ton Field-specific 0,0002 Field-specific Field-specificCH4 ton/ton Field-specific Field-specific Field-specific Field-specificnmVOC ton/ton 0,00003 0,005 Field-specific 0,0033 SOx ton/ton 0,001**** 0,001**** 0,001**** Field-specific PAH** 5 gram/ton N/A N/A N/A 12 PCB** 6 gram/ton N/A N/A N/A 0,22 Dioxins** 6 gram/ton N/A N/A N/A 0,00001

* If neither measured or field-specific emission factors for NOx are available, sjablon values are listed in “forskrift for særavgifter”. ** Not reportable for other than well testing ***Applicable for engines with rpm between 200 and 1000. For other values reference is made to “forskrift for særavgifter”. ****According to new requirements only 0,05 weight % sulfur in diesel are allowed, this gives a new factor of 0,001.


5Sourceforthefactors:NorskOljeogGassEnvironmentalProgrammePhaseII,ProjectC01.EmissionsandDischargesfromWelltesting,avKjelforeningenNorskEnergi.31.05.1994.Tabell1.1

EEH‐table updates in chapter 7 The EEH‐table ‘FugitiveEmissionsAndVenting’ is updated. In the EEH‐table ‘Combustion’ a new type of turbine is added, ‘WLE’.



CombustionOperationsTable25EEHinputtable:Combustion

Column Normal Value / Comments Operator The name of the Operator StructureType Combustion ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location Source State if the burning takes place in:

Flare Turbine Engine Boiler Oven Well test Well cleaning Bleed off from burner boom Other

o Other sources include, inter alia, direct emissions of CO2. Fuel Fuel gas, liquid fuel, oil burning or direct emissions TypeOfTurbine This specifies turbine type: DLE, SAC or WLE DieselBurnt (tonnes) Amount of diesel combusted GasBurnt (m3) Amount of gas combusted OilBurnt (tonnes) Amount of oil combusted CO2Emission (tonnes) Amount discharged CO2 from combustion operation NOxEmission (tonnes) Amount discharged NOx from combustion operation nmVOCEmission (tonnes) Amount nmVOC discharged from the combustion operation CH4Emission (tonnes) Amount discharged CH4 from combustion operation SOxEmission (tonnes) Amount discharged SOx from combustion operation PCBEmission (kg) Amount discharged PCB from combustion operation (oil burned during well test.) PAHEmission (kg) Amount discharged PAH from combustion operation (oil burned during well test.) DioxinesEmission (mg) Amount discharged Dioxin from combustion operation (oil burned during well test.) OilDownfall (tonnes) Fallout of oil from the combustion of oil during well testing

Loadingandunloadingofcrudeoil Table26EEHinputtable:LoadingAndStorageOfCrudeOil

Column Normal Value / Comments Operator The name of the Operator StructureType LoadingAndStorageOfCrudeOil ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location Type Storage or loading of crude oil TotalVolume (Sm3) Total quantity of oil loaded or saved on installation EmissionFaktorCH4 (kg/Sm3) The emission factor for CH4 EmissionFaktorNMVOC (kg/Sm3) The emission factor for nmVOC TeoreticalEmissionBaselineNMVOC (kg/Sm3) Theoretical emission factor for nmVOC without emission reduction

equipment. Required data received from Industrial Cooperation.



DirectemissionsofmethaneandNMVOCTable27EEHinputtable:FugitiveEmissionsAndVenting

Kolonne Normalverdi / Kommentarer Operator The name of the Operator StructureType FugitiveEmissionsAndVenting ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location SourceId Source of emissions as given in table 22 Methodology Method used to calculate emissions for the relevant source, alternatives are

given in table 21. Fate The fate of the emission. Alternatives:

Common measured vent Local vent Sent to flare Recycled Not on installation

VOCEmission (tonnes) Direct emissons of nmVOC CH4Emission (tonnes) Direct emissions of CH4

WellTestTable28EEHinputtable:WellTest

Column Normal Value / Comments Operator The name of the Operator StructureType WellTest ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location Wellbore Well name as given by NPD. WellTestType Indicates whether it is well test, well cleanup or bleed off from burner boom TotalOil (tonnes) Total amount of oil generated during well testing. OilRecovered (tonnes)

The amount of oil recovered.

DieselBurnt (tonnes) The amount of diesel being burned. Diesel is usually used to under-balance the well during startup of the well test.

GasFlared (m3) Amount of gas flared during well testing. Reference

GastracerTable29EEHinputtable:GasTracer

Column Normal Value / Comments Operator The name of the Operator StructureType GasTracer ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location TradeName Trade name of tracer Used (kg) Consumption of tracer Emission (kg) Emission of tracer




Emissionsfromcombustion Emissionsarenormallycalculatedbymassbalanceprinciplefromfuelconsumptionbyemissionfactors.Thefuelcanbeburntgas,flaregas,naturalgas,diesel,fueloilorcrudeoil.Emissionsaretheindividualcombustionresidues(excessair,nitrogenandwatervaporarenotincludedintheemissionregistration).Combustionemissionsshouldbereportedsothattheemissionfactorcanbeeasilycalculatedafterwards.SpecifytheamountoffuelburnedineachturbineiftheturbineshavedifferentNOxemissionfactors. Calculatingemissionsduringcombustionofgas:

33 1000/*1000 SmtonfSmquantityGastonU ii (3)

(4)Calculationofemissionsfromthecombustionofdieselandoils:

tontonftonquantityFueltonU ii /*

Table30ExplanationofthecomponentsintheequationsforcalculatingCO2emissions,usingemissionfactors.Equation(3)and(4).

Component Unit Description

iU Ton Amount released of Gas i

i Gas type; CO2, NOx, CH4, etc.

if ton/1000 Sm3 ton/ton

Emission factor to calculate the amount of spilled gas by combustion of gas, diesel or oils

Field‐specificand/orequipment‐specificemissionfactorsaretobeusedasmuchaspossible.Onlywhenspecificfactorsarenotavailable,emissionfactorsspecifiedinsection7.1.9EmissionFactorscanbeused.

DeterminationofCO2emissionfactorofcombustionForthecalculationoftheCO2emissionfactorthefuelgascarbonnumberisused.Thecarbonnumberisadirectfunctionofthefuelgascomposition.Ifthisisnotavailable,theCO2emissionfactorcanbecalculatedfromthegascalorificvalue.Itisthoughassumedthatthefuelgasanalysisisavailableasdocumentationforthecalculatedemissionfactor.CalculationofCO2emissionfactorfromnetcalorificvalue:

5771,0*0724,02

NCVfCO

(5)

CalculationofCO2emissionfactorfromgrosscalorificvalue:

5771,0*0658,02

GCVfCO (6)

Table31ExplanationsofthecomponentsoftheequationsforcalculatingCO2emissionfactoraccordingtothecalorificvalue.Equation(5)and(6).


2COf ton/1000 Sm3 The emission factor for CO2. Multiply with the burned gas volume to find emitted quantities of CO2.

NCV MJ/Sm3 Net Calorific Value; Net calorific value of the gas combusted GCV MJ/Sm3 Gross Calorific Value; Gross calorific value of the gas combusted

EmissionsofCO2fromCO2treatmentplant(forexample,whenthegasinjectionsystemisdown)shouldbereportedunder“OtherSources"inEEH,butwithoutquantitiesofburnedgasordiesel.



DeterminationofNOxemissionfactor Engines IfNOxemissionscanbedeterminedbymeasuringtheactualNOxintheexhaustgas,thisshallbeusedforreporting.MeasurementofNOxemissionsshallbeconductedundernormalandrepresentativeoperatingconditions.SamplingandanalysisperformedbyNorwegianStandard(NS),orotherinternationalstandardwhereNSisnotavailable.Ifsuchmeasurementsarenotavailable,source‐specificemissionfactorcanbeused.Source‐specificemissionfactoraredeterminedbyNPDforfixedinstallationsonthecontinentalshelf,theNorwegianMaritimeDirectorateformobiledevicesandNorwegianEnvironmentAgencyforlandbasedfacilities,uponapplicationbythetaxable(emissionowner).Ifneithertheexactdischargenoremissionfactorisavailablefortheconsumedfuel,calculationofemissionscanbedoneaccordingto‘Forskriftomsæravgifter,FOR‐2001‐12‐11‐1451’.Anexampleofthecalculationoftheemissionfactoristousemanufacturer‐NOxfactor.ThisisoftendescribedasgNOxper.kWhusedenergy.Conversiontodischargequantityper.1000Sm3fuelgasordieseltonsdeterminedusingthefollowingformula:

KMkWh

NO

Hff

X 1**

0000001

*

(7)

Table32‐ExplanationofthecomponentsoftheequationsforcalculatingNOxemissionfactoraccordingtothegivenemissionfactoringNOxper.kWh.Equation(7).


XNOf ton/1000 Sm3 ton/ton

The emission factor for NOx is multiplied by the burned gas volume / fuel to determine the quantity of NOx discharged.

kWhf g NOx / kWh Emission factor per amount of energy

H kWh/1000 Sm3 kWh/ton

Calorific value of the fuel. If the calorific value of own diesel is not known, 11900 kWh / ton are used.

M Efficiency of the motor. Specified by manufacturer. K Efficiency of any catalyst. Specified by manufacturer.

TurbinesAnexampleofthecalculationoftheemissionfactoristousetheturbinevendorenteredNOxemissionsbasedontheloadontheturbine.ThisisoftendepictedasagraphindicatingtheNOxconcentrationasafunctionoftheperformanceoftheturbine.Figure2isintendedasadescriptiveexampleandshouldnotbeusedinreporting.

Figure2ExampleofNOxemissionsfromtheturbineloadfactor.

0

50

100

150

200

250

300

350

0 5 10 15 20 25Performance

pp

mv

NO

x



EstimatetheaverageloadontheturbineoverthereportingperiodandreadtheNOxemissionsinppmv,whichisthenconvertedtotonsNOx/1000Sm3fuelgas.

DeterminationofSOxemissionsfactorfromcombustionofgas

SOxemissionsfactorfromcombustioncanbedeterminedbymeasuringtheSOxintheexhaustgas.Ifsuchmeasurementsarenotavailable,theemissionfactoriscalculatedasshownbelow.ThegascontainssmallamountsofH2S.DuringcombustionisconvertedintowaterandSOx,mainlyintheformofSO2.GasanalysisindicatestheproportionofH2Sinthefuelgas.Theemissionfactorcanbecalculatedusingthefollowingformula:

39 /10*7,2*2

Smtonkf SHSOX

(8)

Table33ExplanationofthecomponentsoftheequationforcalculatingtheSOxemissionfactoraccordingtothegivenamountofH2Sinthegas,measuredinppm,(Equation(8).


XSOf ton/1000 Sm3 The emission factor for SOx. Multiply factor with the burned gas volume to find quantities of SOx discharged.

SHk2

ppm The amount of H2S in the combustion gas

2,7*10-9 Ton/Sm3

Conversion factor to calculate the emission factor for SOx from H2S amount of fuel gas. See below for the derivation of this factor.

Normally the concentration is in the order of 2.5 ppm, which gives an emission factor of 6.77 * 10‐9 tons SOx/Sm3. SOx consist mainly of SO2. It is therefore based in SO2 emissions to calculate SOx emission factor. CalculationofSOxfactorfromcombustionofgasThetemperatureissetat15°C. Table34MolarmasswhencalculatingtheSOxfactorbycombustionofgas

Component Mol mass Unit H2S 34,08 Gram/mol SO2 64,06 Gram/mol

Table35CalculationofnumberofmolesofSin1Sm3gas

Number of moles S in 1 Sm3 gas Equation:

RT

PVn

nRTPV

Pressure P= 1 Atm. Volume V= 1000 Liter Gasconstant R= 0,0820575 Liter Atm / mol K Temperature T= 288,15 K Moles n= 42,2925 Mol

AfactorforSOxmassintonscanbecalculatedbasedon1ppm(partspermillion)ofH2Siscombustedwithfuelgas:



Table36CalculationofmassSOxMass SO2 from 1 Sm3 med 1 ppm combusted H2S Amount H2S i 1 Sm3 gas 4,22925*10-5 mol Amount H2S i 1 Sm3 gas 0,0014413275 gram Mol amount SO2/mol amount H2S

1,87969 ton

Mas SO2 pr. 1 Sm3 burned 0,002709 Gram Mas SO2 pr. 1 Sm3 burned 2,7*10-9 Ton

SOxemissionscanbecalculatedusingtheamountofH2S,expressedasppm,fromafuelgasanalysis:SOx[ton]=2.7*10‐9[tonnes/Sm3]*amountofH2Sinthefuelgas[ppm]*amountoffuelgas[Sm3]ThespecificSOxfactorisgivenby:SOxfactor[tonSOx/Sm3fuelgas]=2.7*10‐9[ton/Sm3]*amountofH2Sinthefuelgas[ppm]

DeterminationofSOxemissionfactorfromcombustionofdieselandfueloilSOxemissionsfromcombustionfactorcanbedeterminedbymeasuringtheSOxintheexhaustgas.Ifsuchmeasurementsarenotavailable,theemissionfactoriscalculatedasshownbelow.Fordieselandfueloilthesulfurcontentisgiveninpercent.Theemissionfactoristhen:

tontonk

f SxSO /2*

100 (9)

Table37ExplanationofthecomponentsintheequationforcalculatingtheSOXemissionfactoraccordingtothegivenH2Samountinthediesel,measuredin%.(Equation9).

Component Unit Explanation

XSOf ton/ton The emission factor for SOx. Multiply factor with the burned oil/diesel volume to find emitted quantities SOx.

Sk Percent Amount of sulfur in diesel fuel or heating oil.

2 Ton/ton

Conversion factor to calculate the emission factor for SOx from sulfur amount in diesel:

206,3206,64

SmassMolarSOmassMolar x

CalculationoftheSOxfactorfromcombustionofdieselandoilTocalculateaSOxemissionfactorforthecombustionofdieselorotherliquidfuelssuchasforexamplewelltesting,onehastoknowthesulfurcontentinthefuel;thisisnormallygivenasweightpercent.Table38MolarmasswhencalculatingthefactorSOxduringcombustionofdiesel

Component Molar mass Explanation SO2 64,06 Gram/mol

Example:•AmountofH2Sequalto2.5ppm•Amountoffuelgasis110000Sm3.SOx=2.7*10‐9[ton/Sm3]*2.5*110000Sm3=0,743kgThespecificSOxfactoristheninthiscase6.75*10‐9tonSOx/Sm3fuelgas



Component Molar mass Explanation S 32,065 Gram/mol

MolarmassSO2permolarmassSinthefuelisthen64.06/32.065=1.99782EmissionsofSOxcanbecalculatedusingthequantityS,definedastheweightpercentasgivenbythesupplierofthefuel:SOx[tons]=1.99782[ton/ton]*amountSinfuel[%]*amountoffuel[tons]ThespecificSOxfactorisgivenby:SOxfactor[tonsSOx/tonfuel]=1.99782[ton/ton]*amountSinfuel[%]

DeterminationofCH4emissionfactorsfromcombustionCH4emissionsarereportedonlyforcombustionofgas.CH4emissionsfromthecombustionofdieselfuelandoilarenegligible.CH4emissionsfactorfromcombustionexhaustgasisdeterminedbymeasurements/analysis.Ifsuchmeasurements/analysisarenotavailableonemayuseNorwegianOilandGasnormalfactorsspecifiedinchapter7.1.9.

DeterminationofnmVOCemissionfactorsfromcombustionnmVOCemissionfactorofcombustionisdeterminedbyemissionmeasurements/analysis.Ifsuchmeasurements/analysisarenotavailable,onemayusetheNorwegianOilandGasnormalfactorsasspecifiedinchapter7.1.9.

DeterminationofthefalloutofoilfromthewelltestDuringcombustionofoilatthewelltest,someunburnedoilwillfalldownintothesea.Unlessmorespecificdataisknownitshallbecalculatedfalloutof0.05%ofthetotalamountofburnedoil.RecommendedemissionfactorsforsuchPAH’s,PCB’sandDioxinsaregivenin

Example:Theamountofdieselis1,000tons,andsulfurcontentis0.04%.ThenSOxemissions:SOx=1.99782*0.04/100*1000tons=0.8tonsThentheemissionfactorwillbe:SOxemissionfactor=1.99782*0.04/100=0.0008tonsSOx/tonfuel



Table 24.

DeterminationofemissionsfromloadingandstorageofoilEmissionsduringloadingandstorageofcrudeoilareestimatedbytheindustrycooperation.Requireddatawillbereceivedfromhere.First,theamountofevaporatedCH4/nmVOCiscalculated.ThisindicateshowmuchCH4/nmVOCthatisemittedfromthestorageandloadingofcrudeoilforinstallationswhereitisnotimplementedemissionreductiontechnology.

nmVOCCHnmVOCCH ADFVOAM // 44* (10)

Table39Explanationofequation(10)Component Unit Explanation

nmVOCCHAM /4 Ton Total amount of evaporated CH4/nmVOC during storage or loading of crude oil.

VO Sm3 Volume of crude oil stored or loaded. ADF Ton/Sm3 Evaporation factor. Specifies the amount of CH4 or nmVOC that evaporates per

Sm3 of crude oil stored or loaded. ForinstallationswithinstalledemissionreductiontechnologyitcanbecalculatehowmuchCH4/nmVOCthatisrecycledandnotemitted.

GRDFAMTAMGM nmVOCCHnmVOCCHnmVOCCH *** /// 444 (11)

Table40Explanationofequation(11)


nmVOCCHGM /4 Ton Recovered amount of CH4 / nmVOC, i.e. vaporized quantities which are captured

by recovery equipment.

nmVOCCHAM /4 Ton Total amount of evaporated CH4 / nmVOC during storage or loading of crude oil.

Calculated in equation (10) AMT % Part with technology. The part of crude oil stored or loaded with emission recovery

technology activated.

nmVOCCHDF /4 % Design factor. Specifies how much of the evaporated quantities being recovered.

GR % Recovery Regularity. Specifies the regularity of recovery plant, when this should be used.

Theemissionsfromthestorageandloadingofcrudeoilcanthenbecalculated:

nmVOCCHnmVOCCHnmVOCCH GMAMUM /// 444 (12)

Table41Explanationofequation(12)


nmVOCCHUM /4 Ton Emitted amount. The amount of CH4 / nmVOC emitted.

nmVOCCHAM /4 Ton Total amount of evaporated CH4 / nmVOC during storage or loading of crude oil.

Calculated in equation (10)

nmVOCCHGM /4 Ton Recovered amount of CH4 / nmVOC. That is vaporized quantities which are

detected by reclamation equipment. Calculated in equation (11)

WellTest Chapter7.2.4summarizesalldiesel,gasandoilprocessedduringthewelltest.Gas,oilanddieselvolumesaretomatchburnedquantitiesgiveninthechapteroncombustionoperationsinchapter7.2.1.EmissionsofPAHs,PCBsanddioxinsshouldbereportedforwelltest.SeeTable25foremissionfactors.



Duringcombustionoperations(Section7.2.1)itshouldalsobestatedamountofburntoil.Thisamountshouldmatchtheamountgiveninthewelltesttable(section0)andcalculatedaccordingtoequation15below:

oil.ofamountreclaimed‐oilofamountTotaloilburntofAmount (15)




Emissionfromcombustion

Register burned amounts in the reporting system (environmental accounting). This information should match the reported amount to NPD for the calculation

of CO2 and NOx tax

Calculating of emission factors. This is done based on fuel analysis and equipment specifications

Notify the

responsible adjust data

Not approved

Annual reporting to EEH. Writing comments and

drawing graphs

Extracting data from the environmental accounting

system.

Calculate emissions from all components from the burned volume and emission factors

Approved

Generate reports (KPI’s )

Quality Assurance Are all emissions reported? Has the emission factor changed

from previous years? Does it correspond with combustion gas

analysis?

Are the emission factors of the same unit as the standard factors?

The discrepancy need to be explained If greater?

Are the fuel consumption comparable to previous years?

Have there been equipment changes which resulting in change of emission / emission factors?

Is diesel to emergency generator, testing of fire pump, etc.

included? Are the emissions from diesel calculated based on volume or tonne. Are the correct factors used?

Does the volume fuel burned match the reported amount to

NPD for the calculation of CO2 and NOx tax?

Does the factors and emissions match the annual RNB reported to

NPD?




Emissionfromloadingandstorageofcrudeoil

Collect data from the industry collaboration Notify the


Not approved

Annual reporting to EEH. Writing comments and

drawing graphs

Extracting data from environmental accounting.

Approved

Add data to the environmental accounting system


Quality Assurance

Is the volume of storage and loaded oil correct?

Is the data from the industry collaboration wrt amount loaded with emission reduction technology correct?

Is the regularity and efficiency of VOC recovery plants correct?

Is the data consistent compared with previous years' emissions?

Are all emissions reported? Are the plans for reductions of emissions from storage and loading followed?

+ Internal routines for quality assurance



DirectEmissionsofmethaneandNMVOC

Determine the sources of direct emissions of methane and

NMVOC that are present at each installation (Fate).

Determine quantification method for the sources leading to emissions

Notify the


Not approved

Annual reporting to EEH. Writing comments and drawing graphs

Extracting data from the environmental accounting system.

Calculate the direct emission of methane and NMVOC for the sources leading to emissions

Approved


Add 1% or 3% of the total emissions to take emissions from smaller sources into account

Quality Assurance Are all relevant sources included? Are there any sources that are not relevant?

Are there any leaks that should also have been reported under Section

8 ‐ Accidental discharges?

In cases where facility specific method is used, is the method documented?

Is the most accurate method used for calculation of emissions for each source?




8 ACCIDENTALDISCHARGES

ForcompaniesthatuseSynergyorequivalentineventreporting,acutespillsarerecordedinthesystemtogetherwiththeamountandtypeofthevariousemissions.


GeneralReportingonanannualbasisdoesnotreplacereportingofspillsthatarenotifiableundernotificationregulations.“PollutionControlAct§38”definitionsofspills:"Withacutepollutionmeanspollutionofimportance,whichoccurssuddenly"ThereportshallstatehowtheOperatormaintainsfollow‐upofspills:

Learningfromexperience. Measurestoreducethenumberofemissionsandthemagnitudeoftheemissions.

Inthischapterallunintentionaldischarges,spills,etc.,alsoofwater‐baseddrillingfluidsshouldbereported.Itshouldbenotedthattheplannedemissionsreportedinchapter2and4shouldnotbereportedhere.AnaccidentaldischargecanbeconsideredasacutepollutionalthoughlimitssetinpermitsissuedpursuanttothePollutionControlAct§11,isnotexceeded.Anexampleofthisisanabnormaldischargesituationwithhighconcentrationsofoilinwaterforashorttime,althoughthisdoesnotresultinexceedingthepermitintermsofaveragepermonth6.

AccidentaloildischargesAllaccidentalspillsofoilfromtheinstallationsshouldbereportedhere. Table42Overviewofgroupingforreportingoilspills.

Type of spill Definition Diesel All accidental spills of diesel. Diesel used and released in conjunction with the well treatment and

reported the chemicals, should not be included. fuel oil 1-3 Accidental spills of fuel oil. Crude oil All accidental spills of crude oil. Waste oil All accidental oil spills of waste oil Other oils All accidental spills of other oils*

*Hydraulicoilsshallbereportedasaccidentalchemicalspill Itshouldbenotedthatspillsofoil‐baseddrillingfluidsshouldbereportedinSection8.1.3.

6 Ref.GuidanceforManagementRegulations§29



AccidentalspillsofchemicalsAllaccidentalspillsofchemicalsshouldbereportedhere.Table43–Overviewofgroupingforreportingaccidentalspillsofchemicals.

Type of chemical Definition Oil-based drilling fluid All accidental spills of oil-based drilling fluid. Synthetic drilling fluid All accidental spills of synthetic based drilling fluid. Water-based drilling fluid

All accidental spills of water-based drilling fluid.

Chemicals All accidental spills of chemicals Table44Evaluationcriteriaandcategoriesforevaluationoftheenvironmentalpropertiesofsubstancesinchemicals

Emissions Category1 Norwegian Environment

Agency’s color- category

WATER 200 Green Substances on the PLONOR list 201 Green Substance covered by REACH Annex IV2 204 Green Substance covered by REACH Annex V3 205 Green Substances missing test data 0 Black Additive packages that are exempted from test requirement and not tested 0.1 Black

Substances that are believed to be or are harmful in a mutagenic or reproductive manner4 1.1

Black

Substance on the list of priority chemicals or on OSPARS priority list7 2 Black Substance on REACH candidate list8 2.1 Black

Biodegradability <20% and log Pow ≥ 55 3 Black

Biodegradability <20% and toxicity EC50 or LC50 ≤ 10 mg/l 4 Black Two of three categories: Biodegradability <60%, log Pow ≥ 3, EC50 or LC50 ≤ 10 mg/l5

6 Red

Inorganic and EC50 or LC50 ≤ 1 mg/l 7 Red

Biodegradability <20% 4 8 Red

Polymers that are exempted from test requirement and not tested9 9 Red

Potassium hydroxide, sodium hydroxide, hydrochloric acid, sulfuric acid, nitric acid and phosphoric acid

104 Yellow

Substance with biodegradation> 60% 100 Yellow

Substance with biodegradability 20% - 60%

Subcategory 1 - expected to complete biodegrade.

101Yellow

Subcategory 2 - expected to biodegrade to substances that are not hazardous

102

Yellow

Subcategory 3 - expected to biodegrade to substances that may be hazardous

103

Yellow

Sum 10 1 Categories in Table 44 shall be consistent with categories given in Table 16. 2 Commission Regulation No 987/2008. 3 Norwegian Environment Agency must consider whether the substance is covered by Annex V.

4Themutagenicandreproductionharmfulsubstancesareexplainedasmutageniccategory(Mut)1and2andtoxicforreproductioncategory(Rep)1and2,seeAppendix1toRegulationlabelingofhazardouschemicals,orself‐classification5Datafordegradabilityandbioaccumulationshallbeinaccordancewithapprovedtestsforoffshorechemicals



6Thelistofprioritysubstancescanbefoundatmiljostatus.no/prioritetslisten7 OSPARListofChemicalsforPriorityAction(Revised2013)(Referencenumber2004‐12).Thelistcanbefoundhere:http://www.ospar.org/work‐areas/hasec/chemicals/priority‐action.8Substancesonthecandidatelistcanbefoundhere:http://www.echa.europa.eu/candidate‐list‐table9Jf. Aktivitetsforskriften §§ 62‐63. 10 The sum should match the number of chemical spills reported in Table 8‐2 when the individual substances densities assumed for the calculations.

An environmental assessment of chemicals discharged to the sea should be carried out. Chemicals that are released into the sea shall be evaluated similar to chemicals released during scheduled activities. Details are given in chapter 5.

Accidentalgasemissions Allaccidentalemissionsofharmfulgasesshouldbereportedhere.ExampleofgastobereportedhereishalongasandotherCFCs(chlorofluorocarbons),HFCs,FK‐gases,spillsofhydrocarbongas,andpossiblyotheracuteemissions.Allofhydrocarbons,atarateofover0.1kg/second,shallbereported.ThesamedatawillalsobereportedtotheNPD'sHCLIPdatabase.Consistencyshouldbeensured.

ReportingTablesforEEH

UnintentionaldischargestoseaTable45EEHinputtable:UnintentionalDischargesToSea

Kolonne Normalverdi / Kommentarer Operator Name of the operating company StructureType UnintentionalDischargesToSea ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Facility name as provided by NPD Facility Field name as provided by NPD Location Name of drilling location Type Here the type of spill is selected: Oil or Chemical Category Here the category is entered. Obtained from Table 42 and Table 43. VolumeSpilled (m3) Cumulative volume of acute discharges (m3) SpillReference Internal reference to the spill EventDate Event date EventCause Event cause ImplementedMeasures Implemented measures

EvaluationofunintentionaldischargestoseaTable46EEHinputtable:UnintentionalDischargesToSeaProperties

Column Normal Value / Content Operator Name of the operating company StructureType UnintentionalDischargesToSeaProperties ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD




Column Normal Value / Content Location Name of drilling location EnvironmentalCategory Figures referring to the MDir-class to which the substance belongs. Ref. Table

16 Discharged (tonnes) The discharge of the substance in the reporting year, from the current MDir

class. ThesumofemissionsgiveninTable46shouldmatchthesumofaccidentalchemicaldischargesinTable45.

UnintentionalemissionstoairTable47EEHinputtable:UnintentionalEmissionsToAir

Column Normal Value / Content Operator Name of the operating company StructureType UnintentionalEmissionsToAir ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location GasType Specify type of gas. Free text (eg: CO2, Hydrocarbon Gas) NumberOfOccurences Number of emission incidents Amount (kg) Mass emitted


Nodirectcalculations,butallseparateemissionsmustbecategorizedinoneofthecategorieslistedin Table42 and Table 43 – Overview of grouping for reporting accidental spills of chemicals.

Type of chemical Definition Oil-based drilling fluid All accidental spills of oil-based drilling fluid. Synthetic drilling fluid All accidental spills of synthetic based drilling fluid. Water-based drilling fluid

All accidental spills of water-based drilling fluid.

Chemicals All accidental spills of chemicals Table 44.




Register the accidential spill incident in the reporting system

Retrieving data for each release to the environment. Register this reporting system (environmental accounting)

Notify administrators Adjust data

Not approved



Allocate each release to the type, category and volume classification

Approved


(KPI)

Calculate the number and volume of the emissions, associated with each type, category and volume

classification

Quality Assurance Is the correct unit used? Is the data according to what is recorded

in the incident reporting system? Are the chemical discharges in "Acute

pollution to sea properties" according to "Acute pollution to sea"?

Is the correct density used? Are the emissions to air according to what is recorded in the database HCLIP

to NPD?

Are all spills properly categorized?




9 WASTE


GeneralItisrecommendedthatOperatorsofwastemanagementandwastereportingisorganizedaccordingtotheNorwegianOilandGasguidance,"093Guidelinesforwastemanagementinoffshoreoperations"(WasteGuidelines)andNorsas“Guidanceonsubmissionanddeclarationofhazardouswaste,edition2012”.Onlywastethatisgeneratedorreceivedatthefacility/fieldshouldbereported.Wastefromonshorebaseandmarinesupportvesselsshallnotbereported,unlessitisphysicallytransferredtothefacilityandtransportedordisposedofinsomeway.Thisinformationisnormallysortedandenteredthewastehandler.Emissionsreportshallprovideinformationonhowthewastedisposalonshoreandthecompanythatisresponsibleforprocessingmustbespecified.WasteDisposalbydismantlingtheplatformisnotreportedinEEH,butamountsshouldbestatedinthewrittenreport.

SegregatedwasteTable48Categoriesofsegregatedwaste

Category Definition7 Food contaminated waste

Waste contaminated with food particles and other debris that can cause odors and cuts.

Wet organic waste Food and other organic waste Paper All ordinary paper such as newspapers, magazines, office paper, etc. Cardboard (brown paper)

Cardboard and other brown paper

Wood Defective pallets, planks, assorted wood. Glass Flushed (not washed) clear and colored glass. Plastics Plastic cans, cans, foil, plastic bags and other plastic packaging. EE-Disposal All equipment that requires electrical power or batteries to operate. Cables and wires. Residual waste What remains after recoverable waste and hazardous waste is sorted out. Metal Metal cans, pipes, scrap metal, wire Sandblasting sand Waste from sandblasting not containing dangerous substances Explosives Distress flares and other explosives taken to shore Other Waste that cannot be categorized into categories above

HazardousWasteHazardouswasteshallbereportedaccordingtotheNorwegianOilandGasguidelinesforwastemanagementinoffshoreoperations.Drillcuttingsandmudarereportedhereastreatedonshore,butmustalsobereportedinchapter2.

7Appendix1totheNorwegianOilandGasGuidelinesforwastemanagementinoffshoreoperations.



Pre‐definedcategoriesofhazardouswastethatmustbereportedtoEEHisnolongerused,therefore,table52inlastyear'sguideline(Pre‐definedcategoriesofhazardouswastethatmustbereportedtoEEH)isdeleted.ThewasteisreportedbasedonEWCcodeandwastesubstancenumber.EEHdoesanautomaticmappingagainsttheclassificationgivenintheNorwegianoilandgasguideline'093Guidelinesforwastemanagementintheoffshoreindustry',Appendix2.


SegregatedwasteTable49EEHinputtable:NonHazardousWaste

Column Normal Value / Content Operator Name of the operating company StructureType NonHazardousWaste ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Category Choose the category for the segregated waste. Ref Table 51 SentOnshore (tonnes) Amount of waste in each category

Note regarding the amount of waste generated and the amount of waste end treated: It is not necessarily correlation between the quantity of drilling waste in Chapters 2 and 9, although the waste originating from identical drilling operations. There are three reasons for this:

• Lags in recording and reporting. Generated waste one year could eventually be treated in waste treatment plant the following year. • The data in Chapter 2 is estimated values of offshore drilling operations, while in Chapter 9 the values are based on actual weight.

o In table 2.2 and 2.4 in the annual report total amount of cuttings is calculated from theoretical hole volume and hole factor. Drilling fluid is not included here.

o Imported and exported cuttings in chapter 2 contains cuttings with appendages of drilling fluid o Drilling waste given in chapter 9 is weighted amount of cuttings with appendages of drilling fluid

• The waste is transported to shore. It may be minor adjustments to the amount of waste due to changes in the moisture content of the waste.

The Operator should have procedures to ensure that reporting of waste is consistent and complete, and that there is no double reported.




HazardousWasteTable50EEHinputtable:HazardousWaste

Column Normal Value / Content Operator Name of the operating company StructureType HazardousWaste ReportYear Name of the operating company ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Description EALCode Waste code according to the European Waste List WasteCode NORSAS code of waste SentOnShore (tonnes) Amount of waste in each category that are sent onshore


Normally,thesubcontractorthathandleswastehavealreadyreportedtherequiredinformationtotheOperator.Thisinformationistypicallyprovidedonamonthlylevel,withanannualsummary.




Receipt of information on treated waste

Register this in the reporting system (environmental accounting)

Notify responsible. Adjust data

Not approved

Annual reporting to EEH. Writing comments and making graphs


Approved


(KPI)

Calculate the quantities of sorted waste and hazardous waste in accordance with the reporting criteria

QUALITY ASSURANCE Is all waste sorted into appropriate categories and given proper EWC code and waste code?

Is the amount of waste according to installation's activities? Are there major discrepancies from previous years?

Does the distribution of waste look okay from the average of NCS and according to previous year’s amount of waste?

Are the quantities of waste similar the contractors reported amounts?

Is the drilling waste the same as the last 2 years?

Will some of the waste be reported next year?




PARTII REPORTINGTOTHENRPA

AseparatereporttotheNRPAmustbesubmitted.EEHisadaptedfortransmittingthefiguresforreportinganduploadingthefinishedreportinpdfformat.

IntroductiontohowtoreporttotheNorwegianRadiationProtectionAuthority PollutionControlActfrom1January2011appliestoradioactivecontaminationandradioactivewaste.Thisisdeterminedbyregulation1November2010No.1394onpollutionlawapplicabletoradioactivecontaminationandradioactivewaste.Itisalsoissuedanewchapter16aboutradioactivewasteinthe“avfallsforskriften”.Thismeansthatradioactivecontaminationandradioactivewastenowisgovernedbythesamerulesasothercontaminantsandwaste.AllOperatorsontheNorwegiancontinentalshelfshallsubmitannualreportsofreleasesofradioactivematerialstotheNorwegianRadiationProtectionAuthority(NRPA)underthePollutionControlActandtheindividualcompanies'approvals/permits.Itisemphasizedintheintroductionoftheguidelinesforreportingofradioactivesubstancesfromthepetroleumindustry8thatthereportingobligationincludesemissionsofradioactivesubstancesinproducedwater,useanddischargeofradioactivetracersandaccidentalspillsofradioactivematerialsandwaste.OperatorswhodonothaveanydatatoreportshalldeliverasimplereportinwhichitisnotedthattheOperatordoesnothavereportabledischarges.

Reportingrequirements TheOperatorsshallprepareemissionreportswherealloperationaldischargesandallacutepollutionshallbereported.Forfieldswithmultipleinstallationscoveredbyanemissionspermit,thefiguresshallbereportedforeachinstallation.Useoftraceelementsinconnectionwithexplorationdrillingshallbereportedseparately.OperatorsshallenteralldischargedataandtextrequiredtogeneratetheemissionsreportinthecommondischargedatabaseEEH.Thisshouldbedonebythe1stofMarch,thefollowingyear.ThetextshallbeinNorwegian.Acontactpersonforthereportshallbeprovided.ReporteddatashouldbecheckedaccordingtotheNorwegianOilandGasGuidelines.Ifanysectionsarenotrelevanttotheindividualfields/installations,itshallbrieflybeindicatedwhy.Thedesign,numberingandsectionsofthetablesshouldnotbechanged.Theuncertaintyofthemeasurementsand/orcalculationsoftheindividualdischargesshallbeconsideredandindicatedinthereport.9Theguidelinesforreportingradioactivesubstancesindicatethetemplatetobeusedfortheannualreport8.

8 Norwegian Radiation Protection Authority. Retningslinjer for rapportering av radioaktive stoffer fra petroleumsvirksomheten. Available from: https://www.nrpa.no/publikasjon/retningslinjer‐for‐rapportering‐av‐utslipp‐fra‐petroleumsvirksomhet.PDF (Norwegian only) 9NorwegianOilandGasAssociation.085Anbefalteretningslinjerforprøvetakingoganalyseavprodusertvann.(Norwegianonly)ISO/IECGuide98‐3:2008,Guidetotheexpressionofuncertaintyinmeasurement(GUM).



10 INFORMATION

Generalinformationabouttheinstallationistobespecifiedinthischapter.ThiscorrespondstoChapter1oftheannualreporttotheNorwegianEnvironmentAgency.

11 DISCHARGESOFRADIOACTIVESUBSTANCESWITHPRODUCEDWATER

ReportingRequirements

Thischaptershallprovideinformationaboutthemonitoringprogram,includingmeasuringmethod.Thenumberofmeasurementsthatarethebasisfortheresultsshallalsobeincluded.ThequantificationlimitforindividualnuclidesshallbelistedinAnnexincaseswherespecificactivityisbelowthequantificationlimit.Theremightbecaseswheretheanalyticalresultsshowthatthespecificactivityofthatnuclideisbelowthequantificationlimit.Then50%ofthequantificationlimitwillbeusedforcalculatingthedischarges.Anyotherinformationofsignificancefortheresultsshouldalsobementionedinthischapter.MonthlySummaryforeachnuclideforeachinstallationshouldbeprovidedinanattachment.Ifscaledissolvers,otherchemicalsorotherformofremovalofdepositshavebeenused,thismaybeaffectthespecificactivityofradioactivesubstancesintheproducedwater,andshouldbediscussedseparately.Adescriptionoftheoperationsperformed,includingtypeandquantityofchemicalsusedmustbeincluded.Makealsoanassessmentoftheadditionaldischargesthatsuchoperationscanresultin,ineachcase.Themonthswhensuchoperationsareinprogressshallbestated,andanalyticalvalueforTh‐228shallbespecifiedinChapter6,Appendix.Thetypeandamountofchemicalswhichhavebeenused,and/orthekindofremovalmethodshallbeindicated.RadioactivityisreportedinBq/l.TotalactivityinBq(fromproducedwater)shallbeindicated.


Radioactivity Note especially that the radioactive components 226Ra, 228Ra, 210Pb and 228Th are removed from the Norwegian Environment Agency guidelines since this information now is reported to NRPA. These components must be reported to EEH as "Produced Water Radioactivity”.

EEH‐table updates in chapter 11 In the ‘ProducedWaterRadioactivity’ table the comment to ‘TotalUncertaintyInActivityDischarged’is changed from (activity discharged) to (% uncertainty).



Table51EEHinputtable:ProducedWaterRadioactivityColumn Normal Value / Comments Operator The name of the Operator StructureType ProducedWaterRadioactivity ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location ReportMonth The number of the month DischargePoint Can be used to separate the emissions of installations with multiple emission points NuclideName 226Ra, 228Ra, 210Pb eller 228Th SpecificActivity (Bq/l) The concentration of radioactivity in the sample TotalUncertaintyInActivityDischarged (%) Total uncertainty on the discharge to sea (% uncertainty) UncertaintyInLabAnalysis (Bq/l) The uncertainty given for the analysis of the component DetectionLimit (Bq/l) The quantification limit for the radioactive component in the sample Laboratory The laboratory that conducted the analysis Technique The technique used in the analysis Methodology The method used in the analysis

Table52EEHinputtable:ProducedWater

Column Normal Value / Comments Operator The name of the Operator StructureType ProducedWaterRadioactivity ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location ReportMonth The number of the month

DischargePoint Can be used to separate the emissions on installations with multiple emission points

WaterToSea (m3) Amount of water discharged to sea WaterInjected (m3) Amount of water injected

ReportingTables

TablesasdesiredreportedbyNRPA,differslightlyfromthetablesgeneratedbyEEH.ThefollowingtablesshouldbeincludedinChapter2: Table 2.1Emissions ofradioactivesubstances to seawithproduced water

Amount of produced water discharged: m3

Limit in the permission (Bq)

Nuclide Specific activity (Bq/l)

Discharge (Bq) Uncertainty in amount discharged (Bq)

Ra‐226

Ra‐228

Ra‐210

Th‐228

Table 2.2 Amount of radioactive substances to ground/injected with produced water

Amount of produced water to ground/injected: m3

Nuclide Discharged/Injected amount (Bq)

Ra‐226

Ra‐228



Ra‐210

Th‐228 Monthlyoverviewpernuclideshallbegivenintheappendix.

12 USEANDRELEASEOFRADIOACTIVETRACEELEMENT

ReportingRequirements

Thechapterwillprovideinformationontheuseandreleaseofradioactivetracersduringthereportingyear.Thereportshallincludeinformationonwhichcompanyhasperformedtracertestandthepurposeofthetest.Under"Type"inTable3.1itshouldbeindicatedifthenuclidesthatarereportedarewater‐oroiltracer.


Table53EEHinputtable:RadioactiveTracer

Column Normal Value / Content Operator Name of the operating company StructureType RadioactiveTracer ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Wellbore Well bore name given by NPD Type Water-/Oil tracer NuclideName Name of Nuclide used as tracer ActivityUsed (GBq) Consumption of nuclide ActivityDischarged (GBq) Discharge of nuclide ActivityInjected (GBq) Injection of nuclide ActivityLeftInWell (GBq) Nuclide left in the well ActivitySentToShore (GBq) Nuclide sent onshore as waste ActivityInOilExported (GBq) Nuclide in oil exported

ReportingTables

ThetablestobeenteredintothereportdifferslightlyfromthetablesgeneratedbyEEH.Thefollowingtablesshouldbeincludedinchapter3:Table3.1Useandemissionsofradioactivetracesubstances(fieldsinoperation,includingproductiondrilling)Nuclide Type Consumption

(Bq)Dischargestosea(Bq)

Injectedamount(Bq)

Followedhydrocarbonphase(Bq)

Table3.2Useanddisposalofradioactivetracesubstances(drilling)




Nuclide:Well Added

(Bq)Dischargestosea(Bq)

Leftinwell(Bq) Sentonshore(Bq)

Injected(Bq)

13 ACCIDENTALDISCHARGES,ACCIDENTETC.

Thischaptershallprovideanoverviewofaccidentaldischargesofradioactivesubstancesinthereportingyear.Furthermore,itmustbestatedhowthelessonslearnedwithregardtothefollow‐upofspillsareaddressed.

Table54EEHinputtabell:UnintentionalRadioactiveDischarge

Column Normal Value / Content Operator Name of the operating company StructureType UnintentionalRadioactiveDischarge ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location EventDate EventCause NuclideName ActivityDischarged(GBq) ImplementedMeasures




14 WASTE

Thischapterwillgiveabriefpresentationofthesystemformanagementofradioactivewastewhicharegeneratedattheinstallationandtakenashore.Seeguidelinesforcompletingthedeclarationform.Thereportonlyincludeswastegeneratedatthefacility.Thecompanywhoisresponsibleformanagingthewasteonshoreshallbespecified.QuantityintonsandtotalactivityinGBqofwastetakenonshorearebasedondatafromthereceivinglocation,oranyothercompanythathascleanedequipmentforradioactivematerialsbeforefurtherhandling.From2011,anew5‐digitwastematerialnumberisincorporatedforradioactivewaste.Thefirstdigitis"3".Thelastdigitindicatesifthewasteisdisposalrequiredornot10.

ReportingTablesforEEH

ThefollowingtableistobereportedtoEEH:Table55EEHinputtable:RadioactiveWaste

Column Normal Value / Content Operator Name of the operating company StructureType RadioactiveWaste ReportYear Year(current reporting year) ActualYear Year (actual year for exploration drilling) Field Field name as provided by NPD Facility Facility name as provided by NPD Location Name of drilling location Description Description of waste EALCode Waste code according to the European Waste List WasteCode NORSAS code for the waste NuclideNames SentOnShore (tonnes) Amount of waste in each category that are sent onshore TotalActivity (GBq)

Previously,hazardouswasteincludingradioactivewastewasreportedinthesametable,'HazardousWasteOther',andinformationfromthetablewerereportedtoboththeNorwegianEnvironmentAgencyandtheNorwegianRadiationProtectionAuthority.Nowtherearetwoinputtablesforhazardouswaste;'HazardousWaste'inchapter9and'RadioactiveWaste'inChapter14,whicharereportedseparatelyfortheNorwegianEnvironmentAgencyandtheNorwegianRadiationProtectionAuthority.

10 NORSAS. Radioaktivt avfall. Available from:http://www.norsas.no/Radioaktivt‐avfall (Norwegian only)




ReportingTables

ThetablestobeenteredintothereportdifferslightlyfromthetablesgeneratedbyEEH.Thefollowingtableshouldbeincludedchapter5: Table 5.1 Radioactive wasteWasteType Description Wasteno.1) Nuclide Wastetakenonshore

Quantity(ton) TotalActivity(GBq)

1)Wastenumberasdefinedinthedeclarationform



PARTIII REPORTINGTOTHENORWEGIANOILANDGASASSOCIATION

15 MITIGATIONMEASURES

NorwegianoilandgasassociationisobligedtofollowuptheRoadMapfortheNorwegianContinentalShelfonbehalfoftheindustry.TheindustryiscommittedtoimplementCO2emissionreductions(CO2equivalents)whichcorrespondstoatotalof2.5milliontonnesperyearwithin2030.NorwegianoilandgasassociationthereforewantsthesemeasurestobereportedintoEEHforfollow‐upandfurtherreportinginrelationtothetargetintheroadmap.ItisnotarequirementtoreportthisinthereporttotheNorwegianEnvironmentAgencybecauseitisnotpartoftheM‐107,buttheoperatorcanreportonthedevelopmentinChapter1,Fieldstatus,ifdesired.ThemeasuresshouldbereportedinthesamewayasallotherdatainEEH,i.e.eitherbyuploadinginformationfromanexcelsheetthatissetupinthecorrectformatorbymanuallyenteringthemeasuresintotheEEHsystem.Onlymeasuresthathavebeenimplementedorstartedduringthereportingyearshouldbereported.AnnualreductionofCO2emissionsshallbereportedforthesemeasures.Futureplannedmeasuresshallnotbereported.Iftheresultofpreviouslyreportedmeasureshaschangedbasedonmoreexperienceormoreinformationabouttheeffectofthemeasure,thismayeitherbereportedasadifferenceorbyupdatingthisintheactualreportingyear.Someoftheparametershavepre‐definedchoices.Thatis‘TypeofMeasure’,hereyouchoosewhetherthemeasureispermanentortemporaryandreferencetoRoadMapfortheNorwegianContinentalShelf,‘RoadmapReference’.Someoftheparametershaveyes/nooptions,noisthedefaultoption.Ifyouwanttochangeto‘yes’clickonthecellandtickthesmallboxthatappears:

Apre‐definedlistoftypeofmeasuresisgiveninthetablebelow.Table56–Listoftypeofmeasures

1. Drainage strategy

2. Well design

3. Machine (Power generation)

4. Waste Heat Recovery

5. Pumps

6. Compressors

7. Flaring

8. Venting methane

9. CO2 capture and storage

10. Electrification

11. Power from renewable sources

12. Energy storage: Batteries

13. Subsea compression

14. Subsea separation

15. Downhole separation



16. LED lights

17. Diesel for electrical operation

18. MEG/TEG optimization

19. Friction inhibitors

97. Structural changes

98. Liquidation

99. Other This list comes from previous reporting of measures to Norwegian Oil and Gas Association, as well as categories in NORSOK S‐003 “Environmental Care”, but the list is not complete. If the measure does not fit any of these categories, the measure can be reported under ‘other’. It is also possible to contact AddEnergy if there is a need to add new types of measures to this list. This can also be done by using the ‘Get Help’ button in EEH and entering the new type of measure that you want. It usually takes a few hours to update the production system. Norwegian oil and gas association can also be contacted if you have any comments or questions. It should also be reported if the measure is a permanent measure, i.e. the measure applies to the entire lifetime, or whether it is a temporary measure that only applies for a limited period. In addition, a reference to Road Map for the Norwegian Continental Shelf shall be chosen, there are two options:

Maritime activities: These are measures that are not covered by the petroleum legislation, but are still included in this reporting because the measures contribute to reduced CO2 emissions from the industry.

Overall quantitative ambition within the 2030 target of 2.5 million tons: The ambition of reducing greenhouse gas emissions includes lower emissions related to power and heat supply to the oil installations, reduced emissions of short‐lived climate drivers such as methane, more efficient use of energy at field‐ and area level, and reduction in emissions associated with drilling operations from mobile rigging. For a more detailed breakdown of types of measures, refer to Table 56.



Analytics

When looking at reported figures in analytics, ‘emission year’ must be chosen to allow for emissions to be distributed

over the years up to, and including, 2030. The sum of emissions over the lifetime is shown at the reporting year:

There are two variables in EEH for emission reduction measures:

‘Estimated reduction in emission’

o When selected together with the emission year, you will see the total annual reduction in

emissions per year summed up for all the measures reported:



o If ‘Type of Measure’ is also chosen, annual emissions per year will be shown for the lifetime of

the measure:

‘Reduction vision 2030’

o When this is selected, together with the emission year, the total annual reduction in emissions

per year will be summarized as total for all measures distributed throughout the years up to and

including 2030. All measures will be distributed to 2030.

o This variable is set up like this because Vision 2030 aims to implement measures that, together, give an annual reduction of 2.5 million tonnes CO2 by 2030.




ThefollowingtableistobereportedtoEEH:

MitigationmeasuresTable57–EEHinputtabell:MitigationMeasures

Kolonne Normalverdi / Kommentarer Operator The name of the Operator StructureType MitigationMeasures ReportYear Year (current reporting year) ActualYear Year (actual year for exploration drilling) Field The field name as given by NPD Facility Facility name as provided by NPD Location Name of drilling location TypeOfMeasure Specify what type of measure it is MeasureDescription Describe the measure PermOrTemp Specify whether it is a permanent or temporary measure Estimated lifetime Estimated lifetime of the measure EstimatedTonnesReduced (tonnes) Estimated emission reduction RoadmapReference The measure's reference to ‘Road map’ for the Norwegian Continental Shelf Co2Tax Specify if the measure is included in the CO2 tax reporting, Yes/No EuEts Specify if the measure is included in the EU ETS reporting, Yes/No NoxTax Specify if the measure is included in the NOx tax reporting, Yes/No IncludedInPlanForEnergyManagement Specify if the measure is included in company plan for energy management Comments Here it is possible to enter free text

Note that ‘Actual Year’ and ‘Location’ are part of the EEH table, but these are not relevant parameters in this reporting. They are included to follow the same set‐up as the other tables in EEH. Data for these parameters will be ignored.

EEH‐table updates in chapter 15 A new EEH‐table, ‘MitigationMeasures’ is added.



LISTOFTABLES

TABLE 1 DEADLINES FOR THE VARIOUS STEPS IN THE REPORTING PROCESS. .......................................................... 11 TABLE 2 CONTACTS FOR QUESTIONS .................................................................................................................... 11 TABLE 3 OVERVIEW OF WHICH CHEMICALS ACCORDING TO NORWEGIAN ENVIRONMENT AGENCY REQUIREMENTS SHALL

BE PRIORITIZED FOR SUBSTITUTION .............................................................................................................. 12 TABLE 4 NPD CONVERSION FACTORS OF OIL EQUIVALENT ..................................................................................... 12 TABLE 5 EEH INPUT TABLE: PRODUCEDWATERRISKASSESSMENT (TABLE 10.4 IN M-107) ..................................... 13 TABLE 6 EEH INPUT TABLE: DRILLING ................................................................................................................... 15 TABLE 7 EXPLANATION OF THE COMPONENTS IN THE EQUATION FOR CALCULATING THE THEORETICAL HOLE VOLUME.

EQUATION (1). ............................................................................................................................................. 16 TABLE 8 EEH INPUT TABLE: OILYWATER .............................................................................................................. 20 TABLE 9 EEH INPUT TABLE: JETTING .................................................................................................................... 21 TABLE 10 EEH INPUT TABLE: PRODUCEDWATERANALYSIS.................................................................................... 21 TABLE 11 DISSOLVED COMPONENTS IN PRODUCED WATER TO BE ANALYZED .......................................................... 22 TABLE 12 EEH INPUT TABLE: CHEMICAL PRODUCT ............................................................................................... 28 TABLE 13 RANGE OF USE FOR CHEMICAL REPORTING ............................................................................................ 28 TABLE 14 FUNCTIONAL GROUPS FOR CHEMICAL REPORTING .................................................................................. 29 TABLE 15 EXPLANATION OF THE COMPONENTS IN EQUATION (2)............................................................................. 30 TABLE 16 EVALUATION CRITERIA AND CATEGORIES FOR EVALUATION OF THE ENVIRONMENTAL PROPERTIES OF

SUBSTANCES IN CHEMICALS ......................................................................................................................... 32 TABLE 17 EEH INPUT TABLE: CHEMICAL COMPONENT ........................................................................................... 35 TABLE 18 INFORMATION ON CALCULATION OF SUBSTANCES’ ENVIRONMENTAL CHARACTERISTICS FOR REPORTING ... 36 TABLE 19 THE POLLUTANTS ON THE LIST OF PRIORITY SUBSTANCES ....................................................................... 38 TABLE 20 EEH INPUT TABLE: CHEMICAL CONTAMINANT ........................................................................................ 39 TABLE 21 – PRE-DEFINED CALCULATION METHODS. ............................................................................................... 43 TABLE 22 – SOURCES OF DIRECT EMISSIONS. ....................................................................................................... 44 TABLE 23 NORWEGIAN OIL AND GAS RECOMMENDED EMISSIONS FACTORS FROM COMBUSTION PROCESSES USING

NATURAL GAS AS FUEL. SHALL ONLY BE USED IF FIELD-/EQUIPMENT SPECIFIC FACTORS ARE NOT AVAILABLE. .... 46 TABLE 24 NORWEGIAN OIL AND GAS RECOMMENDED EMISSION FACTORS FROM COMBUSTION PROCESSES WITH

DIESEL OR OTHER OIL AS FUEL. SHALL ONLY BE USED IF THE FIELD-/RIG-/EQUIPMENT SPECIFIC FACTORS ARE NOT

AVAILABLE. .................................................................................................................................................. 47 TABLE 25 EEH INPUT TABLE: COMBUSTION .......................................................................................................... 48 TABLE 26 EEH INPUT TABLE: LOADINGANDSTORAGEOFCRUDEOIL ....................................................................... 48 TABLE 27 EEH INPUT TABLE: FUGITIVEEMISSIONSANDVENTING ............................................................................ 49 TABLE 28 EEH INPUT TABLE: WELLTEST .............................................................................................................. 49 TABLE 29 EEH INPUT TABLE: GASTRACER ........................................................................................................... 49 TABLE 30 EXPLANATION OF THE COMPONENTS IN THE EQUATIONS FOR CALCULATING CO2 EMISSIONS, USING EMISSION

FACTORS. EQUATION (3) AND (4). ................................................................................................................. 50 TABLE 31 EXPLANATIONS OF THE COMPONENTS OF THE EQUATIONS FOR CALCULATING CO2 EMISSION FACTOR

ACCORDING TO THE CALORIFIC VALUE. EQUATION (5) AND (6). ....................................................................... 50 TABLE 32 - EXPLANATION OF THE COMPONENTS OF THE EQUATIONS FOR CALCULATING NOX EMISSION FACTOR

ACCORDING TO THE GIVEN EMISSION FACTOR IN G NOX PER. KWH. EQUATION (7). ......................................... 51 TABLE 33 EXPLANATION OF THE COMPONENTS OF THE EQUATION FOR CALCULATING THE SOX EMISSION FACTOR

ACCORDING TO THE GIVEN AMOUNT OF H2S IN THE GAS, MEASURED IN PPM, (EQUATION (8). ........................... 52 TABLE 34 MOLAR MASS WHEN CALCULATING THE SOX FACTOR BY COMBUSTION OF GAS ......................................... 52 TABLE 35 CALCULATION OF NUMBER OF MOLES OF S IN 1 SM3 GAS ........................................................................ 52 TABLE 36 CALCULATION OF MASS SOX ................................................................................................................. 53 TABLE 37 EXPLANATION OF THE COMPONENTS IN THE EQUATION FOR CALCULATING THE SOX EMISSION FACTOR

ACCORDING TO THE GIVEN H2S AMOUNT IN THE DIESEL, MEASURED IN %. (EQUATION 9). ................................ 53 TABLE 38 MOLAR MASS WHEN CALCULATING THE FACTOR SOX DURING COMBUSTION OF DIESEL ............................. 53 TABLE 39 EXPLANATION OF EQUATION (10) .......................................................................................................... 55 TABLE 40 EXPLANATION OF EQUATION (11) .......................................................................................................... 55 TABLE 41 EXPLANATION OF EQUATION (12) .......................................................................................................... 55 TABLE 42 OVERVIEW OF GROUPING FOR REPORTING OIL SPILLS. ........................................................................... 59 TABLE 43 – OVERVIEW OF GROUPING FOR REPORTING ACCIDENTAL SPILLS OF CHEMICALS. .................................... 60 TABLE 44 EVALUATION CRITERIA AND CATEGORIES FOR EVALUATION OF THE ENVIRONMENTAL PROPERTIES OF

SUBSTANCES IN CHEMICALS ......................................................................................................................... 60 TABLE 45 EEH INPUT TABLE: UNINTENTIONALDISCHARGESTOSEA .............................................................................. 61



TABLE 46 EEH INPUT TABLE: UNINTENTIONALDISCHARGESTOSEAPROPERTIES ............................................................. 61 TABLE 47 EEH INPUT TABLE: UNINTENTIONALEMISSIONSTOAIR ................................................................................ 62 TABLE 48 CATEGORIES OF SEGREGATED WASTE ................................................................................................... 64 TABLE 49 EEH INPUT TABLE: NON HAZARDOUS WASTE ........................................................................................ 65 TABLE 50 EEH INPUT TABLE: HAZARDOUSWASTE ................................................................................................. 66 TABLE 51 EEH INPUT TABLE: PRODUCEDWATERRADIOACTIVITY ........................................................................... 70 TABLE 52 EEH INPUT TABLE: PRODUCEDWATER .................................................................................................. 70 TABLE 53 EEH INPUT TABLE: RADIOACTIVETRACER .............................................................................................. 71 TABLE 54 EEH INPUTTABELL: UNINTENTIONALRADIOACTIVEDISCHARGE ................................................................ 72 TABLE 55 EEH INPUT TABLE: RADIOACTIVEWASTE ............................................................................................... 73 TABLE 56–LISTOFTYPEOFMEASURES ..................................................................................................................... 75 TABLE 57 – EEH INPUTTABELL: MITIGATIONMEASURES ........................................................................................ 79

LISTOFFIGURES

FIGURE 1 FLOWCHART FOR CLASSIFICATION OF CHEMICALS IN THE GROUP OF 0.1 TO 9 .......................................... 34 FIGURE 2 EXAMPLE OF NOX EMISSIONS FROM THE TURBINE LOAD FACTOR. ............................................................ 51



APPENDIXAHIGHLIGHTINGOFCHANGES

Summary

Chapter3.1.1: Changedthetextregardingdrainagewater. Chapter4.1.1: Addedreinjectedinsection1. Chapter7.1: Changedthetextregardingquota‐relatedemissionfiguresinsection5. Chapter7.1.1: AddedacommentregardingreportingofdirectemissionsofCO2. Chapter7.1.3: Changedthetextregardingdeductionofdiesel. Chapter7.1.7: Changedthenameofthechapterfrom‘Fugitiveemissions’to‘Directemissionsof

MethaneandNMVOC’andchangedlargepartsofthetextinthischapter.Inaddition,thetableindicatingsourcesofdiffuseemissionshasbeenchangedandanewtablehasbeenaddedthatspecifiespre‐definedcalculationmethods.

Chapter7.1.9: CO2factorforflaringischangedfrom3,73to3,72intable23. Chapter7.2.1: AnewtypeofturbineisaddedtotheEEH‐table‘Combustion’,WLE.

TheEEH‐table‘FugitiveEmissionsAndVenting’isupdated. Chapter7.2.3: Changedthenameofthechapterfrom‘Fugitiveemissions’to‘Directemissionsof

MethaneandNMVOC’. Chapter7.3.10: Removedchapter7.3.10,‘Determinationoffugitiveemissions’. Chapter7.4.3: Changedthenameofthechapterfrom‘FugitiveEmissions’to‘Directemissionsof

methaneandNMVOC’.TheFlowchartisupdatedaccordingtonewreportingmethod. Chapter8.1.3: Addedatablewithgroupingforreportingofaccidentalspillsofchemicals.Newtable

textfortable44. Chapter11.2: IntheEEH‐table‘ProducedWaterRadioactivity’theexplanationof

‘TotalUncertaintyInActivityDischarged(%)’ischangedto‘(%uncertainty)’. Chapter11.3: Smallerchangesontablesandtabletext. Chapter12.3: Smallerchangesontablesandtabletext. Chapter15: Anewpartisadded(PARTIII)concerningreportingofmitigationmeasurestothe

NorwegianOilandGasAssociation.InthischapterthereisanewEEH‐table,‘MitigationMeasures’.



APPENDIXBHANDBOOKFORQUANTIFICATIONOFDIRECTMETHANEANDNMVOCEMISSIONS

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044 Recommended guidelines for emission and … · Determination of CH4 emission factors from...

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