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INTRODUCTION

The seismic signatures of SOf11~ 70 oil amLur gas pools areillustrated by the suite of conventional seismic. 3D seismic and VSPdata incorporated into this Geophysical Atl"s of Western CanadianHydrocarbon Pools. These examples span the Phanerozoic fromCambrian to Tertiary and encompasses the lour western provincesfrom southern Manitoba to northeastern British Columbia (Fig. 1).'nlese reservoirs are morphologically diverse 'md representative ofthe broad spectrum of Western Canadian hydrocarbon plays.Incorporated are bars. beaches, channel s'lndstones, deltas, reefs,banks, mounds, subcrops, faults, folds and salt dissolution features.Some of the larger pools are in excess of ]()() km2 in area and pro-

Exploratory drilling for hydrocarbon potential of the WesternCanada Sedimentary Basin has been the focus of the Canadian oiland gas industry for several decades. During this period. explorationactivities have become increasingly dependent on the capabilities ofthe seismic interpreter and the continually improving seismicreflection method. This Atlas documents a s~lccted group of poolswhich are discernable with the current capabilittes of the seismicreflection method. With the continually improving technology thereis a concommittant need for both the geophV'icist and the geologistto access the accummulated experience of t[;~ir predecessors. Thisvillume is designed to not only introduce the novice to the techniqueshut also to allow practising geophysicists a IIII geologists to quicklyeducate themselves in areas where they hav~ not had experience.

The basal beds of the Western Canada Sedimentarv Basin restupon rocks of Precamhri;"l age which me generally r~ferred to as"the basement". The Preclmbrian is comprised principally ofigneous, volcanic, metamllrphic and sedimentarv rocks. Asillustrated in Figures 3 lil !n, the Prccambrian ;urface was denudedby erosion, chiefly in emil Paleozoic time.

The approximate geographical locations of the example hydrocarbon reservoirs and the coal field are depicted in Figure 2, on thegeological distributions map. These cross-sections A-A' throughG-G' are reproduced as Figures 3 to 10, respectively. As iIIustrated inFigure 2, the reservoir examples trend northwesterly across the fourwestern provinces, from southern Manitoba to northeastern BritishColumbia.

GEOLOGICAL OVERVIEW OF THE

E~PLE RESERVOIRS

The incorporated reservoirs are not only geographically widespread, but are stratigraphically, sedimentologically and morphologically diverse as well. These examples span the entire Phanerozoicfrom Cambrian to Tertiary and include a representative suite ofclastic and carbonate, stratigraphic and structural traps. Theseexamples are correlated to appropriate geological sections (Figs. 3 to10) in order to illustrate, on a regional scale, the geological relationships discussed in detail and referenced within each of the individualchapters. Below a brief merview of the stratigraphic relationshipsbetween these examples is presented. This overview is intended toprovide perspective. McCrossan and Glaister (1964) provide anunequalled overview of the geology of the Western Canada Sedimentary Basin.

Throughout most of lile Western Canada Basin, the Precambrianis directly overlain by Cl'htic facies of Cambrian. Ordivician,Silurian or Devonian agc. For the most part these Basal PaleozoicClastics were deposited if! near-shore environments in a subsidingbasin and grade basinward into marine shales, carbonates and/orevaporites facies. Across much of Western Canada these clastics are

Chapter 11 is based on 3-D seismic case studies. The methodologyand application are discussed from both a conceptual and appliedperspective. Spatial aliasing, 3-D migration, cost-effectiveness,acquisition problems and a host of other questions are poised anddiscussed with a view to objectively evaluating this technique. In asimilar manner, VSP case histories are presented in Chapter 12.Innovative acquisition, processing and interpretational techniquesare described in an attempt to elucidate this innovative imagingmethodology.

In chapter 10, several interpreted seismic lines across an exampleTertiary coal field are presented. In contrast to the precedingexample seismic data, these lines were acquired utilizing highresolution seismic recording techniques. These data are extremelysignificant in that they illustrate that seismic techniques can beapplied to the mapping of shallow and thin coal beds. By analogy,the applicability of these techniques to hydrogeology, environmentalgeology and engineering site evaluations is inferred.

Each of Chapters 1 through 10 is prefaced by an Introduction tothe stratigraphy and geological history of the relevant sedimentarysection. Included are the criteria used in the selection of the examplehydrocarbon pools as well as selected bibliographies. These briefoverviews are followed by separate discussions of the examplereservoir, each of which is accompanied by an illustrated geologicsection and an interpreted seismic line. The intent is to document theseismic signatures of each of these selected hydrocarbon pools.Synthetic seismograms, suites of geologic maps and production datais used to elucidate the ideas presented.

As noted the incorporated reservoir examples are economicallysignificant. Each contributes to the reserves of Western Canada,(Introduction Part B). The corresponding example seismic lines arealso significant, not from an economic perspective, but because theyrepresent an educational tool and the technological expertise of ourindustry. These data displays are state of the art. two-dimensional,cross-sectional images of the earth's subsurface. They are extremelyuseful from both an exploration and conceptual point of view. Theyare not only prerequisites for successful drilling but also for expanding our knowledge of subsurface depositional environments. On

the bases of these data, morphological and stratigraphical relationships can be elucidated to an extent not possible with well log dataalone. Seismic data has become the key stratigraphic tool asillustrated in the succeeding chapters. As an aid to interpreting theincorporated seismic data, an overview of seismic signatures ispresented in Part C of this Introduction.

Chapter 1: Basal Paleozoic clastic reservoirsChapter 2: Upper Elk Point reservoirsChapter 3: Beaverhill Lake reservoirsChapter 4: Woodbend reservoirsChapter 5: Winterbllrn/Wabamun reservoirsChapter 6: Mississippian reservoirsChapter 7: JurassiC/Triassic reservoirsChapter 8: Lower Cretaceous reservoirsChapter 9: Upper Cretaceous reservoirsChapter 10: Tertiarv coalsChapter 11: 3D Seismic case studyChapter 12: VSP Clse study

duce from thousands of wells. Some of the smaller reservoirs aresingle well pools. The example reefs typically tower more than 100 mabove their platform facies and are associated with visually anomalous seismic signatures. The channel sandstones at Crystal Field, incontrast, are difficult to differentiate, on seismic data, from theencasing non-reservoir facies.

The example reservoirs are stratigraphically, geographically andmorphologically diverse and yet are all significant from an economicperspective. Each and every one is an exploration success andindicative of the intuition and expertise of the Canadian explorationist. Each of these oil and/or gas pools contributes to thehydrocarbon reserves of Canada and reflects the imagination andtechnological expertise of our industry. This expertise is clearlyillustrated by the descriptions and discussions of the seismic dataincorporated into the 12 chapters.

With the exception" of Chapters 11 and 12, which are based on3D seismic and VSP (lata respectively, the reservoir and coal fieldexamples are catalo~llld chronologically on the bases of stratigraphy. This classification system has proven optimal, for asdiscussed in the Get)!ogic Overview (section II), the reservoirexamples within each chapter are very typically similar with respectto geological history, depositional environments and facies. TheBasal Paleozoic Clastics chapter, for example, is devoted entirely toreservoirs within the halo of clastics deposited about the Peace RiverArch. Similarly the Upper Elk Point, BeaverhiII Lake, Woodbend

and Winterburn/Wabarnlln chapters incorporate reefal reservoirs forthe most part. The Mi"issippian chapter is based on subcrop clasticand carbonate plays. whereas the Lower Cretaceous and UpperCretaceous are devoted to fluvial, lacustrine and marine clasticreservOIrs.

and

Athens;

Ltd',

AND

DISTRIBUTION

PetroleumsPocoCederwall,

PART A: GEOGRAPHICAL

GEOLOGICAL

L.V. Hills, University of Calgary.

N.L. Anderson, Ohio University

D.A.

VI

differentiated into separate formations on the basis of lithology andstratigraphic age. Where undivided these basal Paleozoic clastics arecollectively referred to as "Granite Wash".

Four basal Paleozoic clastic reservoirs are described in Chapter 1.The approximate geographical locations of these pools is shown inFigure 1, while in Figure 5 these reservoirs are correlated to appropriate sites on the geological sections.

As noted, the nearshore clastic facies of Devonian age, generallygrade basinward, into marine carbonates, evaporites and shales. Thecarbonates are the dominant reservoir facies, the encasing evaporitesand shales are typically effective seals whereas the shales are aprincipal source rock. In the Atlas, these Devonian age carbonatereservoirs are discussed sequentially in four chronologically orderedchapters, each of which is based on specific stratigraphic group(s).These chapters are entitled Upper Elk Point carbonate reservoirs,Beaverhill Lake carbonate reservoirs, Woodbend reservoirs andWinterburnlWabamun reservoirs, respectively.

The Upper Elk Point Group, described in Chapter 2, is mainly ofMiddle Devonian age and forms the base of the Devonian system inWestern Canada. It consists of cyclical sequences of evaporitic,carbonate and clastic rocks up to 600 m thick in the plains area.Reef carbonates are well developed in the upper part of the sectionand form the principle reservoir facies. These carbonates consistpredominantly of fringing reef complexes which developed about theperiphery of the main Upper Elk Point Basin and minor sub-basinsand isolated bioherms which developed therein. These reefal carbonates are stratigraphically sub-divided into the following fourstratigraphic units, examples of each of which are incorporated intothis volume: Rainbow Mbr, Upper Keg River Reef Mbr, Keg RiverFm (Senex area) and Winnipegosis Fm. Specifically, in Chapter 2,the seismic signatures of several Upper Keg River Reef and Rainbowmember bioherms from the northern and sOllthern parts of the BlackCreek sub-basin respectively, are described and discussed. Similarly,interpreted seismic data crossing the shelfal carbonates of the KegRiver Fm in the general Senex area and the Winnipegosis Fm reefswithin the main Upper Elk Point basin are presented and analyzed.Herein, the seismic signatures of these carbonate reservoirs arerelated to the height of the respective reefs, differential compactionand, where applicable, the dissolution of Upper Elk Point salts. Thegeographical distribution of the example Upper Elk Point Carbonatereservoirs is shown in Figure 1. The stratigraphic relationshipsbetween these reefal complexes and the encompassing sedimentary

sections is depicted on the appropriate geological sections (Figures 3,4, and 5).

The succeeding Upper Devonian marine transgression began withthe deposition of the Beaverhill Lake Gp, a cyclical repetition ofcarbonates and shales in central Alberta which pass laterally toshales in northern Alberta and carbonates and evaporites in southernAlberta and Saskatchewan. In a manner analogous to the Upper ElkPoint, the Beaverhill Lake reefal carbonates developed as fringingreef complexes about the periphery of the main basin and as isolatedbiotherms which grew therein. These carbonates, from the predominant Beaverhill Lake Gp reservoirs, and are stratigraphicallyclassified as Slave Point Fm and Swan Hills Fm. Incorporated intoChapter 3, are seismic examples of fringing reef and biohernalreservoirs for both of these groups. The seismic signatures of thesereservoirs are relatively subtle primarily due to the low height ofthese reefs. In Figure 1 the geographical locations of the exampleBeaverhill Lake Gp carbonate reservoirs are shown. In Figures 3, 4and 5 these reservoirs are correlated to the appropriate geologicsections in order to place these pools in proper regional perspective.

Further marine transgression towards the south initiated deposition of the succeeding Woodbend Gp and equivalents. This sequenceconsists of two main facies: shale in northern and central Albertaand carbonates and evaporites in southern Alberta and Saskatchewan. Continued subsidence of central Alberta resulted in the progressive southward migration (backstepping) of the more-or-Iess continuous fringing reef complex. These shelf carbonates and the isolatedbioherms within the interior of the Woodbend basin are denoted asLeduc Fm in the plains area and constitute the principal WoodbendGp reservoirs. These reef complexes typically tower 20D m abovetheir platform facies and are encased in a relatively low-velocityshale seal. As a result they generally exhibit relatively anomalousseismic signatures. The geographical distribution of the exampleWoodbend Gp reservoirs discussed in Chapter 4, are shown in Figure2. On the geological sections (Figures 3 and 6) the stratigraphicrelationships between these build-up and the adjacent sedimentarysection are illustrated.

The succeeding Winterburn Gp similarly consists primarily ofcarbonates and clastics. The Nisku Fm (Winterburn Gp) which formsthe principal reservoir facies developed as fringing shelf carbonates,isolated reefs and interreef clastics. Production from the Nisku Fm isgenerally from isolated reefs, closed structures on the shelf andalong the Nisku subcrop edge (pre-Cretaceous unconformity). Thesereefs, (Chapter 5), constitute the principal reservoirs and generate a

broad spectrum of seismic signatures ranging from very subtle tovery anomalous, depending upon the height and extent of thebuild-up and the velocity contrast between these carbonates and theenveloping shale seal. The geographical distribution of the exampleWinterburn reservoirs is shown in Figure 2. Figure 6 illustrates theirstratigraphic position.

The Winterburn Gp grades upwards into carbonates of theWabamun Gp. The latter tongues out to shale in northeastern BritishColumbia but consists of limestone over most of Alberta. It passesthrough a transition of dolomite and dolomitic limestone insouthcentral Alberta into evaporites and eventually evaporitic RedBeds further south. Wabamun Gp reservoirs typically form: 1) wherethese carbonates are draped over underlying features such as LeducFm reefs or remnant salts; 2) along the Wabamun subcrop(pre-Cretaceous unconformity); and 3) where porous, permeablefacies grade laterally into an effective seal.

The overlying Mississippian strata, (Chapter 6), are dominantlyshallow water marine sediments. Biogenic carbonates dominate insouthern Alberta, whereas shale content increases to the north tobecome the major lithology. The original depositional extent of theMississippian sediments was far greater than their present distribution. These strata were extensively eroded during the pre-Permian,pre-Triassic and pre-Cretaceous erosional intervals.

Reservoirs of Mississippian age in the plains area generallydevelop within closed structures along these erosional surfaces.Nearer to the foothills closure can be due to later stages of faulting.TIle seismic signature (Chapter 6) of the example Mississippianreservoirs is a function of the magnitude of the closure and theacoustic impedance contrast along the subcrop. The geographicaldistribution of the example Mississippian reservoir is shown inFigure 2. In Figures 3, 5, 6, 7 and 9 these pools arc correlated toappropriate sites on the geologic sections in order to illustrate therelationships between these sediments and the adjacent section.

The Mississippian is stratigraphically overlain by the Permian,Triassic and Jurassic succession. The Permian in the plains area isrestricted to the Belloy Group in the subsurface of the Peace RiverArea. The Belloy consists of carbonates and sandstones and isunconformably overlain by the Triassic. The Triassic as discussed inchapter 7, is subdivided into three intervals; A, Band C. Interval Aconsists of a transgressive sequence of dark shales and siltstoneswhich grade eastwards in a continental direction into deltaic and bar,siltstones and sandstones and coquina banks. Interval B similarly

consists of transgressive sandstones and siltstones which fine to thewest and are capped by the regressive Halfway bar sandstones.Interval C is comprised of succession of evaporites, carbonates andsandstones and siltstones. These Triassic strata are succeeded byJurassic sandstones and siltstones in Alberta. Within the Willistonbasin, in contrast, the Jurassic is comprised of carbonates,evaporites sandstones and shales. As is discussed in chapter 7,hydrocarbon production from the Halfway Fm is predominantlyfrom sealed sand bodies and erosional structures along the subcropedge. Generally such reservoirs are characterized by subtle seismicsignatures which are a function of the thickness and areal extent andthe associated acoustic impedance contrast along the reservoirfacies/seal contact. In Figure 2 the locations of the incorporatedTriassic reservoir examples are shown. Figures 3 and 5 present thestratigraphic position of these pools.

The Lower Cretaceous comprises continental through marineclastics and shales depmited on and above the pre-Cretaceousunconformity, a surface of extreme erosional relief in places. As IS

discussed in Chapter 8 a broad spectrum of clastic reservoirs arepresent within the plains area. Included arc fluvial channel sandstones, paralic sheet sandstones, beaches, off-shore bars, deltas anddunes. Structural closure can be due to primary depositionalpatterns, compaction. faulting and/or the dissolution of Devoniansalts. As anticipated the seismic signatures of the diverse reservoirschange as a function of the thickness and aerial extent, reservoirfacies, acoustic impedance contrasts between the sandstones andshale seals, associated structural relief as well as numerous otherfactors. The geographical distribution of the selected LowerCretaceous reservoir examples is shown in Figure 2. Figures 3, 5, 6and 8 illustrate the stratigraphical position of these reservoirs.

The Lower Cretaceous is overlain by the Upper Cretaceous, aconformable sequence of marine and non-marine shales and sandstones deposited in and around a shallow inland sea. These strata arepredominantly marine at the base and increasingly continentalupwards. Examples of the two principle Upper Cretaceous reservoirs, the Cardium and Belly River formations are outlined inChapter 9. These formations are generally productive where, asresult of lateral facies charges, sandstones are sealed by shales.Typically, the reservoirs are characterized by lateral amplitudevariations which are indicative of corresponding facies changes. Thegeographical locations of the incorporated examples are depicted 111

Figure 2. Their stratigraphical position is shown in Figure 6.

VII

VIII

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This stratigraphic correlation cM1l1 baed on l,IJHO-dafe lnformCion pnMded btt 1M Gd:lgic &Mwi 01Canada (GSC), the EnergyR~ Corwervalion Board (ERC8). tht AI:MIf1a GeologIc SUlwy. the SaMIt·chewan GeoIogle Survey. the British CckJrnbiI. 08p&l'trnen. of Enetgy, Mines, and PlJtroleum Reeources, MMlana Bureau 01 MinH and Geok:lgy and h Nor1tI Daklta Geologic SurYey. Some of an.~ ITIllYbe~; horMlYer, ages of kwmations are baled on the I'I'lOIt widely accepted ntromlation pr..rcn the petroleum industry lDdsy. we ani 0flI'lain aIIernati'oe irltItprNtIon8 wiI be brtJulitIIlonh and we weIccll'ntthese dleCuISIons as a means of bringing together acIentlftc 1nlonNtion.

we express thanks to our clleru and ooIle8gues whose suggestIonB pmrnpted this wont. we aI80 thank 1Mgeologists from Industry and the Geologic SUrvey of Canade who took the ttme to critique thl8 work.

e

Stratigraphic Correlation Chart:

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IX

Sturgeon S Triassic A (Montney)Rycroft Charlie Lk. A.Spirit R. Halfway FNig Ck. BaldonnelKobes Charlie Lk./HalfwayValhalla Halfway CWembley Halfway BHythe Halfway A

Bow Is. A Glauconite AGrand ForksCountess Upper Mannville DBadger Upper Mannville BTaber Mannville AWesthazel GP SandProvost Upper Mannville BBHayter Dina BHayter Sparky BWainwright RidgeProvost Basl:ll Quartz CHairy Hills-Colony WPeavey-B1airmoreCrystal-Viking A & HPembina-Ostracod EPembina Lobstick-Glauconite GMarten Hills

Turner Valley RundleBlueberry Debolt AlBHummingbird Ratcliff/BakkenViewfield FrobisherSeal Pekisko

Carrot Ck.-Cardium

Pembina Keystone Belly R.Tindastoll-Belly R.

Whitewood-Paleocene CoalJoffre D-3 3DTaber-Lwr. Cretaceous-3DRicinus VSPLanaway VSP

9-19-29-3

7-17-27-37-47-57-67-77-8

6-46-56-66-76-8

10-111-111-212-112-2

8-18-28-38-48-58-68-78-88-9

8-108-118-128-138-148-158-168-17

Alexis Banff AHarmatton ElktonAlida East Frobisher & Alida

POOL

Red Earth Granite Wash AUtikuma Keg R. AEvi Granite Wash POtter Granite Wash F & IMitsue Gilwood ANipisi Gilwood A

Brazeau Nisku K & SWhitehorse NiskuBigoray Nisku D & EPembina Nisku FBigoray Nisku H & KApetowun Nisku

Ante Ck. Beaverhill Lk.Goose R. Beaverhill Lk. A & BSnipe Lk. Beaverhill Lk.Swan Hills Beaverhill Lk. CGift Slave Pt.Slave Slave Pt.Sawn Lk. Slave Pt.Clarke Lk. Slave Pt.

Penhold D-3ALeduc Woodbend D-3AMorinville D-3Rich D-3ARedwater D-3ObedSturgeon Lk. South D-3

Rainbow Keg R. HH-NN-LLRainbow Keg R. PPZama Keg R.Panny Keg R. DTrout Keg R.Tableland WinnipegosisRocanville WinnipegosisAllan Winnipegosis

6-16-26-3

1-11-21-31-41-51-6

3-13-23-33-43-53-63-73-8

5-15-25-35-45-55-6

2-12-22-32-42-52-62-72-8

4-14-24-34-44-54-64-7

CHAPTEREXAMPLE

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EDITOR: GLYNN H. WRIGHT

ASSOCIATE EDITOR: D.M. KENT CONCEPT: W.C. GUSSOW

DRAFTING: B.E. SCOTT, CANADIAN SUPERIOR OIL LTD.

3-13-23-33-4 7-1

PUBLISHED BY THE CANADIAN SOCIETY OF PETROLEUM GEOLOGISTSAND THE GEOLOGICAL ASSOCIATION OF CANADA

1984

COMMITTEE CO-CHAIRMEN. G.N. WRIGHT AND D.M. KENT

SW"N HI ~

~ l. -"

THE WESTERN CANADA SEDIMENTARY BASINA SERIES OF GEOLOGICAL SECTIONS ILLUSTRATING

BASIN STRATIGRAPHY AND STRUCTURE

SECTION A-A': H.T. CRABTREE, M.O. FUGLEM, D.M. KENT, M.E. McDOUGALLSECTION B-B': E.L. BREAKEY, S. CARROLL, G.N. WRIGHT

SECTION C-C': W.J. McLEANSECTION 0-0': J.M. BEVER, J.S. EVANOCHKO

SECTION E-E': P.R. FERMOR, R.A. PRICE, C.R. TIPPETand G.S.C. Paper 84-14

SECTION F-F': D.T.B. DOHERTY, G.N. WRIGHTSECTION G-G': J.H. ARGAN, A.A. HARTLING

4-64-7+

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,PEACE IIIVER

POOL

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fAlHERW1lRICH

3-13-23-33-44-64-77-1

i

PEACE RIVER ARCH

CHAPTEREXAMPLE

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CHAPTEREXAMPLE

2-62-72-8

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B MAJOR UNCONFORMITYFigure 4. Geological section A'-A" (modified after Crabtree et aI.,1984, In: Wright and Kent, 1984).

2-62-72-84-34-46-68-78-88-9

8-108-118-13

Tableland - WinnipegosisRocanville - WinnipegosisAlan - WinnipegosisMorinville D-3Rich D-3AHummingbird-Ratcliff/BakkenProvost-Upper Mannville BBHayter-Dina BHayter-Sparky BWainwright RidgeProvost-BasI Quartz CPeavey-Blairmore

XI

4-34-48-13 8-11 8-9 8-7

8-108-8

2-62-72-8 6-6

A'~

..

H ~!MG8IRDTROUGH

WILLISTON BAl N

RON con HIGHz•0;

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SWIFT CURRENT PLATFORM

~ ~ ii ii ii• .

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~

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THE BAD HILLSALBEATA SASKATCHEWAN

MEADOW LAKE ESCARPMENTISU8-DEVQNIANl

HARDISTY REEF BARRIER

SEA L£VEL

-..

CHAPTEREXAMPLE POOL

. '. ",-. .c'.,..... . .'~ I'-:

.' "SK~1 '~

---""

--LITHOLOGICAL SYMBOLS

I:::::-j SANDSTONE (coarse)

t>H SANDSTONE (medium and fine)

[:::::j SILTSTONE and SANDSTONE (very fine)

DSHALE

~L1MESTONE

~DOLOMITE

• ANHYDRITE

IIHALITE and other EVAPORITES

[:~ ARGILLACEOUS CHERTY STRATA

~~lcOAL

K=:3 IGNEOUS andlor METAMORPHIC ROCKS

B MAJOR UNCONFORMITYFigure 4. Geological section A'-A" (modified after Crabtree et aI.,1984, In.: Wright and Kent, 1984).

2-62-72-84-34-46-68-78-88-9

8-108-118-13

Tableland - WinnipegosisRocanville - WinnipegosisAlan - WinnipegosisMorinville D-3Rich D-3AHummingbird-Ratcliff/BakkenProvost-Upper Mannville BBHayter-Dina BHayter-Sparky BWainwright RidgeProvost-Basi Quartz CPeavey-Blairmore

XI

POOL

Red Earth - Granite Wash AUtikuma - Keg R. AEvi - Granite Wash POtter - Granite Wash F & IMitsue - Gilwood ANipisi - Gilwood APanny - Keg R. DTrout - Keg R.Gift Slave PI.Slave Slave PI.Sawn Lk. Slave PI.Blueberry-Debolt AlBSeal-PekiskoRycroft-Charlie Lk. ASpirit R.-Halfway FNig Ck.-BaldonnelKobes-Charlie Lk./HalfwayValhalla-Halfway CWembley-Halfway BHythe-Halfway AMarten Hills-Wabiscaw & Wabamun

,'lIERH SASUorCHEw,o,N

!•-

._'~~:C_'_~~_'~~:_~'_'__ ~ l~ ,,,,,CANADIA," SliIElO

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1-11-21-31-41-51-62-42-53-53-63-76-56-87-27-37-47-57-67-77-8

8-17

CHAPTEREXAMPLE

_URRAY TAR S.a.HOS

,.

GROSMONT HEAVY OIL

Figure 6. Geological section C-C (modified after Mclean, 1984, In:Wright and Kent, 1984).

1-31-4

I

~ • •• • ,,

2-42-5

8-17MISAI'! GLACIAL CHANNEL

1-13-7

...

1-21-51-63-5

~-----,-~--: ,

.ANHYDRITE

III HALITE and other EVAPORITES

§::~ ARGILLACEOUS CHERTY STRATA

§COAL

K:::J IGNEOUS and/or METAMORPHIC ROCKS


ProRM..NDVlllE REEFIPEAC, RIVER fRINGING REEFI

3-66-8

vTI'"~.J'LA.'

PEACE RIVER Oil SANDS

1<::1 SANDSTONE (coarse)

V:::::ISANDSTONE (medium and fine)

k::jSILTSTONE and SANDSTONE (very fine)

DSHALE

~L1MESTONE

~DOLOMITE


7-27-3

•,

7-8I

PEACE AIVU~ ARCH

7-67-7

""!'lUI

RIIIUlII

.,---001 [RUK

\

I_C-l ALIERTA

6-57-47-5

_l~OO I

-1~••

c

XIII

D'8-6

!

COLD LAU OIL SANDS

*aM~SM(.. r,~(w..JI

OlVER

•,,

8-12I

WllLINGDON

4-5I

REDWATER

!

"

12-11

RIMan· IIlEADOWBROOKI REHT4N: 1GOLDEN SPIKE

9-3 4-24-3

U 1-1~.~•M

8-16 8-148-15 6-1

10-19

_1

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'*

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POOL

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~'" r*'All

- -

,_;- ........ ~ ~_ SEA LfltH

4-14-24-34-55-15-25-35-45-55-66-16-28-6

8-128-148-158-16

9-19-29-3

10-111-112-1

CHAPTEREXAMPLE

, . ' ,

UI'!'£II MAIIIIIVILlE

tA, DES liES

. , ..

. COL~,!,·. AIl.'f~

~!'_-~--

_ANHYDRITE

_ HALITE and other EVAPORITES

§::~ ARGILLACEOUS CHERTY STRATA

g]COAL

~::::J IGNEOUS andlor METAMORPHIC ROCKS


ll~ 1\••

----- ,t£

j::<j SANDSTONE (coarse)

t<H SANDSTONE (medium and fine)

(:::::j SILTSTONE and SANDSTONE (very fine)

DSHALE

~LIMESTONE

~DOLOMITE


SCOlLARD

~-

~-

~-

-

$EALEYH __

XIV

Figure 8. Geological section E'-E" (moclified after Fermor et at,1984, ill: Wright and Kent, 1984).

E'

EASTERN MAIN RANGES

IDOD

2000

~:~~~ Kbz SEA LEVEL

- 5000

6-4 12-2E-

EASTERN FOOTHILLS

PLAINS

!;..

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~

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ORIENTPOINT

SAUD LEPfA I(

EASTERN FRONT RANGES

;..

!!?"~

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MARGARET !1MTN, ~

-------------- ----------

MT. RUNDLE

~---------

SUNDANCERANGE

BREWSTERCK

t'imi

"A

WESTERN FRONT RANGES

------


/:::j SANDSTONE (coarse)

!r]SANDSTONE (medium and fine)

[:::::J SILTSTONE and SANDSTONE (very fine)

OSHALE

~lIMESTONE

~DOlOMITE

_ANHYDRITE


E~::? ARGILLACEOUS CHERTY STRATA

mCOAl

K~3 IGNEOUS and/or METAMORPHIC ROCKS

8 MAJOR UNCONFORMITY CHAPTER_EXAMPLE POOL

6-412-2

Turner Valley RundleLanaway VSP

xv

Figure 9. Geological section 1'-1' (modified :t!wr Doherty andWright, 1984, In: Wright and Kent, 1984),


D SANDSTONE (coarse)

!«I SANDSTONE (medium and fine)

k::J SILTSTONE and SANDSTONE (very fine)

DSHALE

~L1MESTONE

~DOLOMITE

- SUNBURST DOME

,.

,.

,..,

CE.lt.lEIIH

'.

F'

(Sawtooth)

POOL

Bow Is,-A Glauconite AGrand Forks-LwL Mannville DCountess-Upper Mannville DBadger-Upper Mannville BTaber-Mannville ATaber-LwL Cretaceous-3D

~'

8-18-28-38-48-5

11-2

CHAPTEREXAMPLE

ALBERTA SASKATCHEWAN

IQW 'Sl~IIfP' .

CYPRESS HILLS

III ANHYDRITE

11IIII HALITE and other EVAPORITES

~;::~ ARGILLACEOUS CHERTY STRATA

glcoAL

K<J IGNEOUS and/or METAMORPHIC ROCKS


CANADAU.SAMONTANA

8-4 8-3 8-18-5 8 - 2 1

11-2 K'VINc+,

,OW Sll''''."'1' ,.'JIL f. I

1\1£.,,"0 M

FALBERTA SYNCLINE

,.

,.

. //

,,.,

,,.

,.

Slit. LEIfEL

XVI

Figure 10. Geological section G-G (modified after Argan andHartling, 1984, In.: Wright and Kent, 1984).

6-7 6-3

G'lIKlOSE lIlT".

CAfilADIAlllStUElD. .

Alida East-Frobisher & AlidaViewfield-Frobisher

POOL

6-36-7

CHAPTEREXAMPLE

LAKE /lAM/TOU.

... .... ... ... .

• ANHYDRITE


§::l ARGILLACEOUS CHERTY STRATA

§COAL

K~;J IGNEOUS and/or METAMORPHIC ROCKS


~.' .

.....IH.NEJI,VEIt

VALLEY

DSHALE

~LIMESTONE

~DOLOMITE

I>::·j SANDSTONE (coarse)

!\::::I SANDSTONE (medium and fine)

k::jSILTSTONE and SANDSTONE (very fine)


r-

.-

-,.....

.-

.-

lEA Lf....El

XVII

G. Rehwald, Logis Data Systems Ltd.

B. Fransden, Virtual Computing Services Ltd;

P. Howard, Logis Data Systems Ltd; and

INTRODUCTION

With regard to the pool average figures, some features are noteworthy. In general, the average recovery factor for the shallowerclastic reservoirs are less than one half of the recovery for the Devonian carbonate plays. This is partially due to the occurrencc of alarge number of heavy oil pools in the Cretaccous, but is also attributable in part to porosity and permeability differences and distribution, reservoir geometrv, drive mechanisms and recovery schemes.Note that where Devonian reservoirs once contained 57 C;{; of thetotal recoverable reserves of the province, they now contain 44% ofthe remaining recoverable reserves. By comparison the combinationof Triassic, Jurassic and Cretaceous reservoirs which once contained32% of initial reserves of recoverable oil in the province, now contain 44.7% of the remaining reserves. This shift in the reserve trendsof the province suggests that production is becoming more dependent on recovery from shallower, poorer recovery and heavier gravityreservoirs. By comparison, the per barrel capital costs associatedwith the shallower oil arc probably similar to the deeper reservoirs,however, a SIgnificant increase in operational costs because of lowerrates of production can be expected.

Notable exceptions to this generalization are the increases in theproductive significance of Wabamun - \Vinterburn, Elk Point andbasal Paleozoic clastic suhdivisions. All of these intervals show anincrease in the relative contribution to total production in the lastquarter of 1987 versus their contribution to total cumulative production to date. This change is due to the significant reserve andproduction additions to the Winterburn Gp in the West Pembinaarea in the late 1970's, and the ongoing reserve additions to the ElkPoint Gp and basal Paleozoic clastic units in the Peace River Archarea of northern Alberta.

In general the Cretaceous oil reservoirs are less attractive withrespect to reserves and productivity, but are not as capital intensivedue to their shallower depth. Furthermore, the increase in the significance of shallower production indicates that these zones are heingsuccessfully explored for on a more active basis.

icance when production volumes are taken into account. The Lowerand Upper Cretaceous contain some 13% and 25% respectively ofthe remaining recoverable reserves of the province. These factors areall indicative of a change with time in the relative significance ofdifferent stratigraphic wnes. Production and reserve volumes of oilwhich previously were dominated by Devonian reef plays are beingreplaced by Cretaceous pools which, in general, are smal!er, lessproductive, shallower and have poorer recovery factors.

Of the 39 668 oil well completions in Alberta 22 279 (56%) contributed some production in December of 1987. Of the 39 585 gas wellcompletions in the province some 25 691 wells (64%) contributed toproduction in December 1987. Note that some of the "shut in" wellsmay have produced in the 4th quarter of 1987 and may be a sourceof error in the presented tables. Of the total wen count a disproportionate number of these completions occur in the Cretaceoussystem, ie. 24 391 oil and 32 278 gas (Table 3). Note that this disproportionate ratio of the well count does not apply to the same extentin the production volumes of either oil or gas. Cumulative oilproduction has historically been dominated by the Woodbend andBeaverhill Lake groups (28% and 19% respectively). Currentquarterly oil production is dominated by the Lower Cretaceousinterval (26% of the provincial total in the 4th quarter of 1987).

this summation. The pool count made in this section mav be misleading in that pools which contain both oil and gas are normallycounted once as an oil pool, and once as a gas pool.

The largest oil reserves groups in Alberta have historically beenthe Leduc and Beaverhill Lake groups, but are now of lesser signif-

To January 1st, 1988 some 84 567 zones have been completed foroil, gas and water recovery or injection in Alberta. Of these wells47% or 39 668 are oil wells, 43% or 36 555 are gas wells, 1.5% or1286 are classified as gas/oil wells and 8% or 7,058 are classified aswater wells. As previously mentioned many of the wells which arenow classified as water wells may have been previously oil wells butare now water source or injector wells and are not included in the oilwell count. Commingled zones also show only once and are classifiedaccording to the shallowest of the commingled zones.

OBSERVATIONS

Each of the pools recorded on the reserves data tapes wereassigned to one of the nine stratigraphic categories via their associated zone code, then summed and averaged by dividing by thenumber of recognized pools in each zone. Thus, these data can onlybe viewed as averages, in that they account for hoth small and largereservoirs and a wide distribution of reservoir types, ie. light, medium and heavy oil pools. Note also that a discrepancy occurs in therecorded produced volumes of oil between the production data fileand the reserves data. Both data files were current to the secondquarter of 1988, however, the production data were edited to areference data of January 1st, 1988. Data for the tenth category(confidential wells and pools) are not displayed in the Tables.

The reserve figures were summed in two separate runs, one for gasreserves and one for oil reserves. Note that the reserves of bitumen,natural gas liquids, sulphur and solution gas are not addressed in

Note also that gas production recorded on the ERCB productionfile tape differs significantly from production recorded in the ERCBreserves data file. This difference is due to the inclusion of all fuelgas, inert gas, water V;tpour, injected gas and most condensate andnatural gas liquids in the production file. These portions of theproduced volumes are deleted from the "marketable gas production"recorded in the reserves data file.

In order to determine tbe relative significance of the nine stratigraphic subdivisions, two ERCB computer files, the reserves volumeand the production volume were respectively sorted utilizing software of Virtual Computing Services and Logis Data Systems. Toobtain the production segment, each of the 85,000 recorded wellcompletions in Alberta were categorized by their associated zonecode into one of the nine stratigraphic subdivisions, a tenth categorywas also recorded for the undefined (confidential) wens. These wellswere summed over southern, central and northern Alberta, and bytheir major product components; oil, gas and water. These data wercsubsequently totaled and are displayed in Tables 1-4. In reviewingthese data note that the well count is slightly misleading for tworeasons: 1) any single well may be recorded more than once due tomultiple zone completions; and 2) wells which were previously oilproducers, but are now water injectors (in the same zone) do notshow in the oil weI! count, but only appear in the water well count.Total oil production bv zone is slightly misleading in that it does notrecognize any mined oil production.

Note also that the", data may contain some apparent differencesto the above referencnl reports. These differences may be two foldand sourced from eithcr: I) the grouping or selection of the zonecodes (formational grouping) which is unique to this report; and 2)the definition of ga" nil and condensate or the methods of theirgrouping which may v:try within the report. Several of thesedifferences are ann"l:ltcd within the tex1. Note, however, thatmisinterpretation is avuidable by utilizing these data in a relative,ratber than an exact sense.

METHODOLOGY

characteristics, their c'intribution to production to date, andreserves. To a lesser extent these data document changes with time lJ1

the significance of these divisions.

Ltd·,

STRATIGRAPHIC

OF HYDROCARBON

PRODUCTIVITY IN

ALBERTA

PART B:

DISTRIBUTION

RESERVES AND

D. Cederwall. Poco Petroleums

In order to illustrate the relative significance of production fromeach of these nine stratigraphic subdivisions, Tables 1 and 2 wereconstructed. These summary tables address oil and gas respectively.They were derived from computerized data of the Alberta EnergyResources Conservation Board (ERCB) and processed by VirtualComputing Services Ltd. and Logis Data Systems Ltd. Note that thisanalysis is limited to Alberta. The reserves and productivity of theAlberta portion of the basin are analogous to many of the pools ofSaskatchewan and British Columbia which are not discussed in thissection. Reserves and productivities of thesc two provinces are documented in the reports: Saskatchewan Reservoir Annual (1987) andHydrocarbon and By-product Reserves in British Columbia (1986).

Due to the averaging which has been applied to the pool parameters, many of the numeric values shown in Tables 1 and 2 have nodirect application to prospect evaluation. These data represent anoverview of each of the nine stratigraphic subdivisions presented inthis volume and allows comparison of their respective reservoir

The reserves and productivity of the Westcrn Canada SedimentaryBasin are well described in the literature of provincial, federal andindustry agencies and no attempt is made in this overview to restatethese values. These data however, are generally directed either towards an analysis of total reserves and productivity within a portionof the basin or towards the attributes of specific pools and littlework exists on the regional significance of the nine stratigraphicsubdivisions utilized in this Atlas.

XVIII

WELL COUNT

WELL STATUS

OIL GAS GAS/WATER

TOTALOIL WELLS

7,004 21,207 97 2,060 30,368

17,387 11 ,071 823 1,827 31,108

1,651 303 47 238 2,239

1,586 1,204 83 263 3,136

2,300 649 22 220 3,191

2,984 494 31 176 3,685

2,299 232 6 539 3,076

1,294 71 10 78 1,453

1,393 89 1 1,092 2,575

1,770 1,235 166 565 3,736

39,668 36,555 1,286 7,058 84,567 TOTAL WELLS

477. 437- 1. 57- 87- 99.57- % of TOTAL WELLS

ALBERTA CUMULATIVE PRODUCTION PROVINCIAL SUMMARY

Table 3: Summary of productive wells by interval, 1ll Alberta

OIL (M3) GAS (E3M3) WATER (M3) CONDEN (MS)

40/87 CUM + OIL 40/87 CUM +GAS 40/87 CUM40/87

CUM12/87 PROD 12/87 PROD 12/87 12/87

ACEOUS 1,623,222 224,171,187 5,276 3,774,288 207,417,539 17,691 2,197,700 138,615,754 270 19,769

ACEOUS 4,271,699 172,090,507 9,136 10,189,667 530,088,641 6,004 11,241,474 270,535,059 15,670 714,077

RIASSIC 1,131,135 1..0,412,155 1,201 1,342,554 36,820,257 179 2,154,474 36,220,066 2,384 176,273

ISSIPIAN 551,842 66,578,560 967 5,687,140 545,508,349 842 916,759 34,081,867 4,214 2,445,585

ERBURN 1,876,770 130,372,056 847 1,801,336 118,117,978 331 2,264,535 53,503,140 272 75,711

ODBEND 1,970,915 449,077,179 1,528 2,859,582 305,266,907 216 15,952,481 602,480,034 293 1,261,227

LL LAKE 1,882,754 302,159,339 1,533 2,932,195 177,039,489 135 10,499,150 296,998,258 ° 73,416

K POINT 1,370,632 112,895,648 790 434,274 21,553,804 5 1,112,704 28,652,971 55 26,086

LASTICS 1,278,670 98,838,585 809 171,494 9,036,382 1 18,835,723 1,148,654,793 ° 128

DEFINED 69,500 1,084,271 192 446,614 2,720,138 287 405,284 53,292,512 943 15,157

GRAND 16,027,139 1,597,679,487 22,279 29,639,144 1,953,569,484 25,691 65,580,284 2,663,034,454 24,101 4,807,429TOTAL

UPPER CRET

LOWER CRET

JURASSIC/T

MISS

WABAMUN/WINT

WO

BEAVERHI

ELBASAL

PALEOZOIC C

UN

Reserves and production volumes of the Alberta portion of theWestern Canada Sedimentary Basin have historically been dominatedby carbonate plays which occur as subcrop and reefal traps. Although the Paleozoic reservoirs remain strong producers, their overall contribution to the productivity is being gradually replaced bymore numerous but less productive Mesozoic reservoirs. This tendency reflects the maturity of the basin and also shows a tendencytowards conservative investment strategies in moderate risk andmoderate return type plays. Seismic studies including 3D will play anincreasing role in the location and evaluation of these plays.

To January 1st, 1988 there has been some 39 585 gas zone completions in Alberta. A disproportionate number of these wells,approximately 19000 occur in southeast Alberta and are attributableto the Upper Cretaceous production of that area. The most significant initial reserves of gas in Alberta are from the Mississippian andLower Cretaceous intervals, which contained 27% and 31% of thetotal marketable gas production. Production, however, has depletedsome 58% of recognized Mississippian reserves and 37% of theLower Cretaceous gas. Of interest is the fact that some 11000 LowerCretaceous gas wells have at one time produced in Alberta, althoughthere are some 15 240 recognized Lower Cretaceous gas pools. Thisdifference is attributable to the existence of many shut in single wellLower Cretaceous gas pools which have never produced.

These data, when coupled with the increase in the relative contribution of the shallow horizons show an ongoing change in gas production in the province. Although many of the deeper carbonatereservoirs are still strong gas producers there is a slow but continualincrease in the proportion of production from shallow lowproductivity wells.

Of note in the analysis of gas production is the wide variance inthe productivity of the various horizons with the shallower horizonsshowing the highest well counts and the lowest per well productivity.[n the last quarter of 1987 approximately 17 691 on stream UpperCretaceous gas wells produced an average of 2 370 m3/d per well,accounting for some 12.7% of the provincial production. [n thesame period approximately 135 Beaverhill Lake Gp gas wells produced some 2933 x 103m3 of gas accounting for 9.8% of provincialgas production (note that these volumes include solution gas from oilwells).

CONCLUSIONS

XIX

,-------_._------_._--_._----------------------------_.------------------------------------------------------------------------"'--------,

RESERVES AND PRODUCTIVITY OF ALBERTA'S PROVEN AND PROBABLE LIGHT, MEDIUM AND HEAVY OIL POOLS

xx

224

450

1,728

1,201

5,276

1,65185,678

460,103 7,004

24

392

70239

482

309

48455

5814,637

815 14,263

8431,673

1,696

31

30

158

14.0493951318469459 i 786I

82,085 222,046380357 17.3 153.392 25.0 4,307

wo

I :3

I

0.Z;;-- ~

-"6:?

ELK POINT

WOODBEND

UPPER CRETACEOUS

-------------

--------------

-------------------------

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I w;- 0 II -' 0 w 0 Z I W O! r;, Z w::J 2 ~ f- ::;) Z Z I 0 f- 0. '00 II ~ a: 0 II ,::;' >- 2 0 ~ 0 a

~----------~-----II--~-l~~--I_~---~---~r-II~-~-~-~-~~-__~--+--+->-----+--+--4--4--~-Z--~--~--~4--~--I--+--4--4--}:~~~-~~!.--!~~138 1,623 2.197 3.4 114.4110.1

-- 1---- -. -- -- -- --f--- 1 .J.. --~---+-----~--~---+_--~---+--+--+--4--_t--_1f_--t_--+_--+--+---+--4---+----+ ..-'---.-I----I--~

w••~Em~o~~~:~~~g::~;~:~~ .9:~~I_.L~ I ~ Mm OM .5 ~+1-,2-1-5_t-8-8-9_t-9-,-%-6_t-4-1-+_2-,0-4-64-1-,0-8-8_+-95_8_+-9-5-+4-5-5-,7-2-8~1-7,-3-87~-9-,-13-6~-8-,2-5-1~-1_.7_2_7 270 4,27111,241 b.l: 10.2 I 26.6

JURASSIC & TRIASSIC 318 46,598 Tl 505 35 37379 61 I 1,028 I 11 151 i 251 30 121 277 I 495

MISSISSIPPIAN - --+-2--57-~-7-1-----3--8--4--+-8-.3-3-+-1-0,-5~-3~-rl 1,655 872 13,334 53 262 195 67 13 100,615 1,586 967 619 66 I 34 551 916 62! 43 I 3.4

i I---+---+----------+--~-+---.--+ t "l--r-----r----

".~7' _..27 _'6'. 1_ '-"- .:'. 33' '807 7~.'~ I ~"6+1-82-2-+_1-6-,9-5-9+-6-3-~2-3-0_1f_2-1-1_1-,-19--+-4-7_+7-6-,5_3-2+-2_,3.-°_°+-8-4-7_1-1 ,_4_53~__~_~-: ~_._5_3--1r-'8:+2:r~_8_3-f~~.810 ,454,81414iJH 846 223 147,561 I 78 ,5.3991 26 i 3032 :266 2,949 853 15,142 65 150 145 5 8 89,966 2,984 1,528 1,456 449 I 602 1970 11t; 952 i 143 I 280 1'2?

---r---- f · --~---f----l·--.. -t---- ---+--+---+--+---r------+--+----i--+--+----t-- l---- --~t-+-+-=

I '8' , , ''7 16 "": 3'~2 2,::6 8'cr:~'-C J3+8€_0~-:_:2_1~-::-.-::-:-+-:-:-+--::-:-t-:--:-:-~-:-)-f--:_:_11-1

-73

-,-1-35+-2-,2-9--9 ~~_53_3_._"~ -'02~29~ ~:~ ._0_A:l_'3_:+~+~'

345 88,849 147,627 6.7 48,857 8 1,984 19 511 II 848 568 281 650 357 156 35 1,687 822 15,766 51 174 174 ° 5 113,153 1.393 809 584 98 1.148 1,278 18,835 17.4 ,,' 62 ' 79CLASTICS .---r- ...--+--_+----.~--+_--+_--~---.-+---+_--+--_+_--_+_--_+_--+----t_--t_--t---t---f_---1f_---+--+---+----- --+..-

ITable 1: Summary of oil reserves In Alberta

RESERVES AND PRODUCTIVITY OF ALBERTA'S PROVEN AND PROBABLE GAS POOLS

(J)<{(')

W....Jenu;;::>E0 0

0;:'a:Il.....J

~

(J)....J....JWS....J

~of-

UPPER CRETACEOUS 581 400 380 146 11,3 233 61 5.001 1,840 21,207 17,691 3,516 797 2,718 33 22 5.5 300 .91 316 65 218 .06 207 80 127 3,774 207 2.73 12.9

LOWER CRETACEOUS 1,662 1,153 1,135 409 31.4 726 63 8,440 15.240 11,071 6,004 5,067 963 554 2.5 22 7.4 306 .88 109 70 76 .07 75 27 48 10,189 530 18.85 34.9

JURASSIC &TRIASSIC

MISSISSIPPIAN

WABAMUN & WINTERBURN

WOODBEND

BEAVERHILL LAKE

ELK POINT

BASAL PALEOZOICCLASTICS

188

964

304

397

269

26

3

143

635

195

288

204

20

2.4

128

612

144

213

128

17

2.1

24

352

73

132

28

5

0.2

1.9

27.0

5.6

10.2

2.2

0.3

o

103

259

71

81

99

12

19

80

42

49

38

77

70

90

306

704

372

375

105

22

6

735

845

540

212

242

499

28

303

1204

649

494

232

71

89

179

842

331

216

135

5

1

124

362

318

278

97

66

88

1,929

1,923

1,430

1,812

1,509

1,485

2,204

417

834

691

1,773

436

44

227

4.2

7.4

8.5

15.2

7.4

14.6

3.6

13

11

12

10

7

7

12

16.5

16.1

12.2

15.7

14.6

13.9

20.5

340

332

312

327

326

326

342

.85

.85

.87

.88

.83

.80

.85

257

1,141

563

1,877

1,114

53

11

75

74

69

68

76

76

76

195

752

361

1,360

844

41

86

.10

.11

.13

,16

.12

.15

.14

175

724

268

1,009

530

35

76

34

417

136

625

118

9

6

141

307

133

384

411

45

70

1,342

5,687

1,801

2,859

2,932

432

171

36

545

118

305

177

21

9

8330

75.04

60.45

147.06

241.32

96

4.6

19.5

6.2

9.8

10.0

1.4

0.005

Table 2: Summary of gas reserves in Alberta

NOTES: 1. RAW GAS INCLUDES ALL MEASURED, PRODUCED GAS VOLUMES AT THE WELL HEAD, AND IS NOT EOUIVALENT TO MARKET GAS IN THAT IT CONTAINS H,S, CO"WATER VAPOR, FUEL GAS SUPPLY AND REINJECTED GAS; WHEREAS MARKET GAS PERTAINS ONLY TO THE SALEABLE PORTION OFTHE RAW GAS. IN MANYINSTANCES THIS INCLUDES THE ENERGY EQUIVALENTS OF CONDENSATES AND NATURAL GAS LIQUIDS (NGL'S).

2 PER POOL AVERAGES ARE DERIVED BY SUMMING FOR THE ZONE AND DIVIDING BY THE NUMBER OF POOLS.3, PER WELL PRODUCTION AVERAGES ARE HIGH DUE TOTHE INCLUSION OF SOLUTION GAS IN THE TOTAL RAW GAS PRODUCTION VOLUMES,

XXI

iii II ~

1

"r

1'1"11'1'1111'

30010

"I'

I i

"I'

"I' °i

I

II I rl J[ IIIJI"1Id JIll[, J Iullli[! ,

"I'I" ,

I I I ITfTlII I !

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.1000 J.501iJ 2090 2:190

Di5t~noo (METRES)

!l<I1ot0 1.~g0 aoaca 2~'U'

5 ••

:..>1<>1<1

5 ••

•

il lil i't !I,II!ii:if:1rlifjl' I'

I I Ij I j II,

Ili'IIIII!III!IIIIII"J,

-, I fill ,llljI,,

[llI"i;/IIi'", illJj,j iL,~ IiJt

I~

j:, 11I1I111I "'!I",J1!llbTmii"if:,::IJ"I, , j "

•

Iil. e _

@.4 --.-

,. ,-

•"r~'

,

TRACE I' ~"i~

T " "I' or "I' "i!,.,

ill flill [Ilil fi'll r 'rlifi''j''lli Ijf

I I-

""I'i!0

"'I!I 'I0

~. 2 -

. '1"1111' ril '1111:11 rII' ,I II-- /J!ll~L,.;!- r Ir ' ilijilili l

f!,. , ',ll"'"- I' ,f <'!

TRACE I' J-aJ- 'Ot

" I,., ,,- i '1

i,..fI P!I.I!r'lll 'IWII i.li.:I. 1.1.,.' I r- 'I: IIIlili - hnil'

"~~ II ili'jHi ii'llilli'I'1 j,., - _,,w,.,I) tJllfl r NI1il(%1 !

- "'ii, "iIJ~li<i'.rrm~." "111,1'1 " '1 1,:,1; f

- .111:,-, ::,1, l jFigure 12. The focusing "rid defocusing effects of curved andirregular surfaces.

SEISMIC SIGNATURES

---~-~-----,I I

LATERAL CHARACTER TIME - STRUCTURAL

'~ r~v ARIAnONS STRUCTURAL VELOCITY-

ASSOCIATED GENERATEDWITH (RELIEF)

PROMINENTSEISMIC

REFLECTIONS

VARIATIONSIN THE

SEISMICIMAGE OFSPECIFIED

LITHOLOGICALINTERVALS

II:. "'i: i. , J, : ",I ':.LUll~:T~"'C'hL .. I 'U~_U.LL..lLL: . ,. - '[

~ ~] 3500 m/s 3 ~_'" =0 t=

;: 1_6_00_0_~/~----~2 300-0-m-_3=

Z ~ ~ r~ ~ ~ 3500 m/s]. §-

CO :.:::j t=

~~'" ""i"'!'" "l"'i:'II'i""i~

Distance (METRES)

'" 10e 200 390 4130 S\t0 600 700 fl00 '900

DI STANCF 9~~~ .~~ .~~ ~0""OI I I I ITRACE # 5.1 .. •• .. •I I I I I

9.9 ~ --j Wt'II--------

-----

r ,I

-9.2 -

1-------- ! }- " ,- ,-

'~~ 'Ii 11 Ill~ It--

'r~!!fJlilll~------

) I--

,1JI dIrrJjr~li,-, ' II---9.4 - I '- - ';

Figure 10, Seismic signatures (Anderson and Brown, 1987).

Figure 11, Phase andlor amplitude variations can result from lateralchanges in acoustic impedance contrast.

Time-structural relief is comprised of both velocity-generatedrelief and structural relief. Velocity-generated relief is primarily dueto lateral variations in average velocity associated with facieschanges (Fig. 14) and with local thickness variations (Fig. 15). Structural relief (Fig. 16) can be syndepositional or postdepositional inorigin. Postdepositional relief results from geological phenomenasuch as erosion, faulting, salt dissolution and differential compaction. Time-structural relief which is independent of the particularreservoir is not considered to be a component of its seismicsignature. Again, as a word of caution, it may be noted thatspurious time-structural relief can result from erroneous staticscorrections (Fig. 17) or from overzealous processing (Fig. 18).

residual static error on the seismic section and "corrected" out,creating a spurious "reef' or the like below the salt-bearing unit.

There are many modelling studies in the literature which demonstrate the seismic effects of various stratigraphic features: Harmsand Tackenberg (1972), Meckel and Nath (1977), Neidell andPoggiagliolmi (1977), Gelfand and Lamer (1984), and Jain (1986),and Anderson et al. (1989) to mention just a few. Many of theseideas are incorpora!ed into the seismic signature classificationscheme used by Anderson and Brown (1987) and presented here (Fig.1). In Figure 19, a geological model and a corresponding two-dimensional synthetic seismic section are presented in order to show someof the components of the seismic signatures associated with reefs.Table 4 illustrates one method of classification. Anderson andBrown (1987) suggest that modified versions of this classificationscheme may be prepared and applied with advantage for any reservoir of interest, whether carbonate or clastic. Such tables may thenbe used as qualitative and quantitative benchmarks against whichuntested anomalies could be compared. In cases where untestedanomalies deviate significantly from the classification norm, soundexplanations, based on all available geological and geophysicalinformation, should be developed to account for the observeddeviations prior to drilling.

and

Athens',SIGNATURES

Calgarv'.,University,

of

SEISMICOhio

Canada Northwest Energy.

University

C:

Brown,

Greenwood,

L. Anderson,

PART

J.R.

N.

E.

The seismic signatures (or distinguishing seismo-geologicalfeatures) of western Canadian hydrocarbon reservoirs are generallymade up of two basic components: lateral character variations andtime-structural relief (Fig. 10). Ideally both components are geophysical representations of geological features and are primarily functions of the morphology of the reservoir and the nature of the basinin which the reservoir facies were deposited: clastic or carbonate;shale or evaporite.

Lateral character variations can be classified either as phase andlor amplitude changes along seismic events or as changes in the pattern of a sequence of events originating from a stratigraphic unit orinterval (this pattern is herein referred to as the seismic image). Suchlateral character variations, or seismic representations of stratigraphic features, may include: variations in acoustic-impedancecontrast (Fig. 11 ) which may arise from gradational or abrupt facieschanges; focusing and defocusing of reflections from curved orirregular surfaces (Fig. 12); diffractions; constructive or destructiveinterference as a function of varying interval thickness (Fig. 13), andamplitude variations which may be the result of differential attenuation. Following Sheriff (1973), attenuation is defined as anyreduction in the amplitude of seismic waves. SlIch as produced byspherical divergence, energy absorption, reflection and scattering.The term differential attenuation is here defined as any lateralchange in the amplitude of a seismic event which is attributable tolateral variations in the attenuative properties of the relevant rockformations.

Character variations which are independent of the reservoir arenot considered to be components of the seismic signature. In thisregard, one should be cautious of apparent (i.e. spurious) charactervariations which can result from the application of, for example,inappropriate stacking velocities, or of erroneous static corrections.The latter could arise, for instance, in an are:, where fairly recentsalt dissolution has created a collapse feature tint extends a considerable way up the section. This feature cOll!d be interpreted as a

XXII

Distance (METRES)

,!

:::j1· --L. - .

,l'...j

.. _. JJ

......I

3'I

~ ::: ~

l]]JIt::1rl:liJJJIllX.:U 1 L

~ :·J1lLfHIJIJ111 HJII.111 HII:I]]1] tlll.1 Jj )J·I·:!:.' I: I tl1f illl I j 1 l __ .

~ .-.rrr Ij! 1 t:1 :'1 f, 1 -- I· :.-jJ ~) ) Li r j j j .' ---

~--H r ·]111 J,irn Jlu:::m:: ::i' 11111niil Hllllirm'll11i --- .1.I.f:'

Il. a

1.2

Il.ll

1l.6

DISTANCE ..I

TRACE II ~,

I

1.11

1l.4

Il.S

9: 190 20~ 390 400 590 690 709 8010 900

, I I I I I I ' I ' ,"" --d-' II i ,'II" U.lll'1 ',i III i 16

1111! I iii I i 1I1I iii i! Iii ~

-4 ======:j'~ --4=

;,;; g:t- 5\ground level -t~1f) 4 1=

~ ~'"~~j' 3 t'" '" ~0. ... 2 t.,..B .---------lOr; CSl =! .1-

~ ~:--r-nl II ! 1111 I ! ! I ! I ! 11111 i ! ! II i I :TTlI ! I ! FN II I I I ! I J I i, "! !! [I - I i

DI STANCE ~

ITRACE II "

I

1l.2

1.2

1l,2

1l.1l

1l,6

1l.4

1.1l

Figure 17. Apparent time·structural relief can be the result of eitherpoor statics corrections or control.

! ,'jjii,iiiIIL.L-_

~

'=-

2:

Distance (METRES)

o .1.00 200 300 400 500 600 700 800 900

=1($ =:;13I ~N ~

~

Figure 16. Time-structural relief can be caused by structural relief inthe subsurface.

Dl STANCE"I

TRACE: II ",'I,

21

II'!31

o 0

Q.? --

Q,4

TRACE 51 41

Q.Q -.--11111 fff'li~ I'l! I~ I .11~ II1I

Figure 15. Velocity-generated time structural relief can be caused bv. .lateral variations in the thicknesses of lithological units.

Basement

Horizon 2

Horizon 1

3.0Surface

Distance km, 0 2 0

DEPTHIVELOCITY MODEL

I Layer 12000 mi.1 1 :0,5

P1 M1 • M2 M3

I Layer 2 , 3000,

4000 m/sl 2222 ml:i m/s I,11 :~,33i311:0.25 .' 11:0.45

P2/ Layer 32000 mi.11 :0.5 s

3000 mi.

0,0o

500

1500

2000

E

'"~ 1 000

"o

DISTANCE i L,.. .... ...... ...... ..,.~... ...... L""'''I I I I I I i

TRACE It "I'" "'r -r 81 La 11 •

I I , , 1 I ! I '

~'J' '~!I II I J I' 11'111111"'11111

0,0 F 5 }'J J '"'),' '#,))ljr,lil ! ill1lljI!!~ Jj' '" "l' .. ,. " ~<f~f~:th>~~

o,a =--- .. , , ' ,I"lll . LI1 , .. JllJLI!JrJ! Ill)]: I ,

Figure 14.

Figure 13. Constructive and destructive interference is a function ofinterval thickness and acoustic impedance contrast.

XXII'

Hydrocarbon and By-Product Reserves in British Columbia, 1986.Province of British Columbia, Ministry of Energy, Mines andPetroleum Resources, Petroleum Resources Division publication.

Jain, S. 1986. Suitable environments for inversion techniques: amodel study. Journal of the Canadian Society of ExplorationGeophysicists, v. 22, p. 7-16.

Kohrs, B.M. and Norman. D.K 1988. Western Atlas Internationalstratigraphic correlation chart of petroleum producing areas ofCanada and northern United States.

Pfl(JM'N(~f SEISM'C HEfLECTORS

srGNI~ICA"T C~AAACTER VAAI~TIO"S ASSOcrATEO WITH

S'G~I"CA~T CHARAC~EH V~RIAT'ONS ~SS()eIATEO W'T~ ,-~(

5E'S"'C '''AGES C' THe REeF AND THE O~~-~HF FAC'E',

""."'-"F'C',S

SIGNIFICANT STRUCTURAL RELIEF

S'~N'~'CANT V(LoeHr· GENE"A1E~ T'ME - ST~UCTU~e

",,"CFe R[['

·'[L'''';-'"El ,TlC'oH"$

E"UTGF' DR""~

REEF EXAMPLE ____

250 50ca 759 1.00\31 1250 .1500 .1 750. 2099

. , I ' I I .iii I :l~L II iii ill I ji Ii iii i .jllil Ii II L

lSI .- +-

~ ~

~;~ i.'~~~~~l' l~ if) --=l 3 1\ ·--"c1~4=--~~

,s; ~ ~~ ~ ~ 2

"'~~~O:l~ .1~

, ! ! IT i ' I I ] I ! i I I j I i Iii! ! i ! I I ! I I ! i I Ii j ! i j I

Distance (METRES)

2

Distance (METRES)

5

199 209 390 400 500 600 709 899 909

I

..~ ~., ~

~ it') 4... =J-------~-.------~...lI: UNCONFORMITY..... ~~ 3,s;'"......'",g:~~I------------c----------i=,

~-=h.-rrrrrTTl--'-'-TT1...,.,noTT~-rrrrrTTl"""TT1...,.,noTTTTT..,-j='-~

'"DJSTANCF ..

TRACE II I51'

McCrossan, R.G. and Glaister, R.P. (Eds.) 1964. Geological Historyof Western Canada. Alberta Society of Petroleum Geologists.Calgary, 232 pp.

Meckel, L.D. and Nath, AK 1977. Geologic considerations forstratigraphic modelling and interpretation. In: Payton, C.E.(Ed.), Seismic stratigraphy - applications to hydrocarbonexploration. American Association of Petroleum Geologists,Memoir 26, p. 417-431\.

Neidell, N.S. and Poggiagliolmi, E. 1977. Stratigraphic modellingand interpretation-geophysical principles and techniques. In:Payton, e.E. (Ed.), Seismic stratigraphy-applications tohydrocarbon exploration. American Association of PetroleumGeologists, Memoir 26. p. 389-416.

"·f'·," C'"'·O·'"'''G"RO" e" >'c"'00~

eLF.fe·",,-

'V"" '."'("A-"',k0'G {~l

""E:' "_'TFC'"~

,·,,,rs C"'·O'NA',,·O

ree'" T~' OOU

"'" RfU 'CC'NT'CT

!-YE,,-S CR·;·"~'T'~"

HeNG POST - "ueUl"T~RS

bO" _~ll'

(CHQ"""

"R'·C"L -'''('fONU_""~;"~ CY

,eL "OlOCS

":·,e,zo,

REFERENCES

Table 4: Classification scheme for the seismic signature of a typicalDevonian reef.

9.2 --

0.4-

0.0-

DJ STANCF .. ...... ..... .1-21010 21010ea .... ...... 6.00 81QQ .1-000 I I I I II I i i , TRACE II s. ... 3. a. •... 3> 2.L ., • I II I I I I

•• l. fl..jUlI ItlJ1UIliliU1111IUllll!l:l0.2

0. a

0.6

1.0

0.4

0.0

TRACE II

0.2 =

~\l.a _

Podruski, J.A, Barclay, J.E., Hamblin, AP., Lee, PJ., Osadetz,KG., Proctor, R.M., Tavlor, e.e., Conn, RF. and Christie,J.A 1988. Conventional Oil Resources of Western Canada:Geological Survey of Canada, Paper 87-26.

Saskatchewan Energy and Mines, Reservoir Annual, 1987.Petroleum and Natural Gas, Miscellaneous Report 88-1.

Wright, G.N. and Kent, D.M. (Eds.) 1984. The Western CanadaSedimentary Basin: A series of geological sections illustratingbasin stratigraphy and structure. Canadian Society of PetroleumGeology, Calgary.

Sheriff, RE. 1973. Encyclopedic dictionary of explorationgeophysicists, Society of Exploration Geophysics.Energy Resources Conservation Board, 1987. Alberta's Reserves of

Crude Oil, Oil Sands, Gas, Natural Gas Liquids and Sulphur:Energy Resources Conservation Board Report ST 88-18.

Anderson, N.L. and Brown, RJ. 1987. The seismic signatures ofsome Western Canadian Devonian reefs, Canadian Society ofExploration Geophsicists, v. 23, p. 7-26.

Gelfand, V.A and Lamer, KL. 1984. Seismic modelling. LeadingEdge, v. 3, no. 11. p. 30-34.

______ , , Hinds, Re. and Hills, L.V.1989. Seismic signature of a Swan Hills (Frasnian) reef reservoir,Snipe Lake, Alberta. Geophysics, v. 54, p. 148-157.

Figure 19. The seismic model illustrating some of the components ofthe seismic signature of a reef: 1) time-structural relief due tostructure; 2) velocity-generated time-structural relief; 3) lateralvariations in seismic image due to a change in facies; and 4)amplitude and/or phase variations due to: A) lateral changes inacoustic impedance; B) the focusing and/or defocusing effect ofcurved or irregular surfaces; and C) constructive and/or destructiveinterference.

~-

! ---\l.6

ll. 0

0.4

1.0~ - --

Figure 18. Aesthetic processing can transform the seismic signatureof an erosional low into that of a carbonate reef.

Harms, J.e. and Tackenberg, P. 1972. Seismic signatures ofsedimentary models. Geophysics, v. 37, p. 45-58.

XXIV

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