TRAPSIZEDISTRIBUTIONS(4‐WAYDIPCLOSURESONLY)

NOVASCOTIAOFFSHORETRAPVOLUMES

Thetotalbasinresourcepoten1alfortheNovaSco1aOffshorewascalculatedusingBEICIP’s3DpetroleumsystemsmodelThemis3D.Themodelwasconstructedusingoutputfromthe3DfaciesmodelDionisos.

Fivesourcerockhorizonsweremodeledusingtheparameterslistedinthetableoverleaf.

Themismodelsthetotalvolumeofhydrocarbonexpelledfromthesesourcerocksis980BnBoe.

Themiscalculatesthevolumeofresourcetrappedinthebasinbycompu1ngthevolumeofdipclosedfeaturesforeachreservoirplayfairway.Inthemodeltherearefiveplayfairways:

1.  Ap1an‐Cenomanian2.  Hauterivian‐Barremium

3.  Barriasian‐Hauterivian4.  Oxfordian‐Tithonian5.  EarlytoMidJurassic

Theinplacereservesarethecomputedbyfillingthedipclosedfeatureswithmodelednettogrossandporosityderivedfromthe3D faciesmodel. The 2D 1me slices from thismodelwas used as the Gross Deposi1onal Environmentmaps onwhich theCommonRiskSegmentMappingwasdone.IntheCRSexercisetheGDEmapswerehandmodifiedtoensuretheyweregeologicalreasonable.NotethattheserevisedGDE’swerenotthenincorporatedbackintoThemis.

SourceRockparameters

Approx.Age

IniNalTOC KerogentypeandiniNalIH DescripNon

APTIAN 122Ma 2%(constant)

III(con1nental)IH=235mgHC/gTOC

(Dogger.NorthSea)‐Opensystemkine1cs‐Vandenbrouke

etal.1999

Poten1alsourcerockintheNaskapishale,iden1fiedinsomewells.

Variableeffec1vethicknessbetween0–100m.

VALANGINIAN 136Ma 1%(constant)

III(con1nental)IH=235mgHC/gTOC

(Dogger.NorthSea)‐Opensystemkine1cs‐Vandenbrouke

etal.1999

Verypoorandscaaeredsourcerock(coalfragmentsindeltaicenvironment,throughtheMississauga

forma1on)Variableeffec1vethicknessbetween0–200m.

TITHONIAN 148Ma 3%(constant)II‐IIImix

IH=424mgHC/gTOCBestdefinedSR,widelyproven.

Variableeffec1vethicknessbetween0–50m.

CALLOVIAN 160Ma 2%(constant)II‐IIImix

IH=424mgHC/gTOCUncertainextentandrichnessduetothelackofdata.

Variableeffec1vethicknessbetween0–20m.

PLIENSBACHIAN(L.M.Jurassic)

196Ma 5%(constant)

II(marine)IH=600mgHC/gTOC

(Toarcian.France)‐Opensystemkine1cs‐Beharetal.1997

Suspected,notproven.Poten1allypresentabovesaltbasinsonly.

Assumedaveragethickness20m.

NOVASCOTIAOFFSHORETRAPVOLUMES

Theporositywasderivedfromtheburialhistoryandmodifiedfortheeffectsofoverpressure.

Usingthisapproachthevolumeofresourceanditsarealdistribu1onintherespec1vezonesisdependentonthefollowing:

1.  Dipclosedvolumes2.  Modelledreservoirdistribu1on,nettogrossandporosity.

Themisassumesthatsaltdoesnotseal.Thereforenosaltclosedfeaturesareincludedinthevolumetrics.Wehaveaaachedastructuralmapinthesaltdiapirprovince.Thisshowsalargenumberofthepoten1alclosuresthatarepiercedwithsaltdiapirsandthereforenotincludedinthebasinresourcecalcula1on.Wethereforeassertthatthebasinresourcepoten1alinanyareawheretherearesaltorfaultclosedfeatureswillbeunderes1mated.

Similarly with respect to reservoir distribu1on, the model assumes a ‘blanket reservoir’ with a smooth distribu1on of net to gross andporosity. We know that this is not the case, par1cularly in the deeperwater areas inwhichwe expectmore channelised and fan typereservoirs.Thereforethearealdistribu1onofthebasinresourcees1mateswillbeflawedindeepwater.

Aaachedthereare7figureswhichwesuggestgiveabeaerimpressionofstructuralstyleandscaleofdipclosedfeatures.

ThefirsttwofiguresareextractsfromthestructuralmapattopHauterivian,thesealingsurfacefortheMiddleMississaugareservoir. OnefigureshowsalargedipclosedfeatureintheareaoftheTantallonwell. Wewouldexpectthisfeaturetobecrossedbychannelsandsshedfromtheshelfedge. ThesecondmapshowsthestructuralstyleintheareaoftheShelbourneandTorbrukwells–anareaofintensesaltdiapirism.No1cethenumberoffeaturesclosedagainstsalt.NotethatthefullstructuralmapisinthePFAAlas.

FollowingthetwomapstherearefivehistogramsshowingtheBulkRockVolumesofallthedipclosedfeaturesoneachofthefivereservoirs.Theyareselfexplanatory.Wehavealsoincludedthefinalbasinresourcehistogramsforcomparison.

Tantallon

HauterivianMFSdepthmap

Shelburne

Albatross

Mohican Shuben

HauterivianMFSdepthmap

ApNan‐CenomanianBRV(Mm3)

0.0

200.0

400.0

600.0

800.0

1000.0

1200.0

1 4 7 10 13 16 19 22 25 28 31 34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79 82 85 88 91 94 97100103106109112

Simple4waydipclosuresonly

Hauterivian‐BarremianBRV(Mm3)

0.0

2000.0

4000.0

6000.0

8000.0

10000.0

12000.0

1 4 7 10 13 16 19 22 25 28 31 34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79 82 85 88 91 94 97100103106109112115118

Simple4waydipclosuresonly

Berriasian‐HauterivianBRV(Mm3)

0

200

400

600

800

1000

1200

1 4 7 10 13 16 19 22 25 28 31 34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79 82 85 88 91 94 97100103106109112115118121124

Simple4waydipclosuresonly

Oxfordian‐TithonianBRV(Mm3)

0.0

200.0

400.0

600.0

800.0

1000.0

1200.0

1 2 3 4 5 6 7 8 910111213141516171819202122232425262728293031323334353637383940414243444546474849505152535455565758596061626364

Simple4waydipclosuresonly

Early‐MiddleJurassicBRV(Mm3)

0

50

100

150

200

250

300

350

400

1 3 5 7 9 111315171921232527293133353739414345474951535557596163656769717375777981838587899193

Simple4waydipclosuresonly

Zonesforvolumesanalysis

Rankingofthedifferentzones

Zone3‐1/3discovered

mmbbls)

Oilvolumeinm

mbb

ls(surfacecon

diNon

s)