Answering the Challenges of Production from Deep … the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation Bob F. Perkins Research

Answering the Challenges of Production from Deep-Water Reservoirs:

Analogues and Case Histories to Aid a New Generation

December 7-9, 2008, Houston, Texas

Program and Abstracts

28th Annual GCSSEPM Foundation Bob F. Perkins Research Conference



28th Annual Gulf Coast Section SEPM FoundationBob F. Perkins Research Conference

2008

Program and Abstracts

Houston Marriott WestchaseHouston, Texas

December 7–9, 2008

Edited by

Kevin SchofieldNorman C. RosenDeborah Pfeiffer

Sam Johnson

ii Program and Abstracts

Copyright © 2008 by theGulf Coast Section SEPM Foundation

www.gcssepm.org

Published December 2008

The cost of this conference has been subsidized by generous grants from BHPBilliton, Devon Energy, Shell Exploration and Production Company, and Schlumberger.

The cost of the Monday night buffet has been subsidized by a generous grant from StatoilHydro.

http://www.gcssepm.org

Answering the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation iii

Foreword

In spite of the great sophistication of the technol-ogy brought to bear on the collection and analysis ofgeological data today, particularly in the oil industry,geoscience as practiced by the majority of us remainsan essentially empirical endeavour not that differentfrom the science practiced by our forebears in the nine-teenth century. They clopped around the country onhorseback, collecting samples, comparing and contrast-ing with their own prior experience and that of otherspublished in the journals of the day. They produceddetailed descriptions, maps and cross-sections, andfrom these derived theories of how the earth hadevolved to its observed state. We travel the globe fromour desks, collecting rock samples and remote sensingdata of a variety of sorts…seismic, gravity, electromag-netic, satellite imagery. And, in our turn we compareand contrast with the data of others and develop ourown theories or build on those of others to explain howwhat we observe became so.

Every so often this stately empirical process isdisrupted when a ground-breaker or iconoclast steps upand rearranges all of our carefully assembled facts to fita new paradigm. Thus, the observations supporting theExpanding Earth hypotheses of the nineteenth throughmid-twentieth centuries were re-ordered and refiledwith some added data to support the theories of Conti-nental Drift and its evolved form Plate Tectonics. Theevolution of sedimentary basins by crustal downwarp-ing in geosynclines filled according to Walther’s Lawhas been replaced by the hypothesis of SequenceStratigraphy, which elegantly explains a whole raft ofprior observations by repackaging them in a “better”framework.

In these cases, and many, many more, our under-standing and ability to interpret the geology we observe(directly or remotely) and place it in a contextualframework is almost entirely dependent on the use ofanalogs. “The best geologist is he who has seen themost rocks” holds as true today as it always has. Thosewho see furthest in the geological sciences stand not onthe shoulders of Newton’s Giants, but have scaled aswarming termite hill of analogs and descriptive exam-ples built up patiently over the years. The GCSSEPMResearch Conferences have a long and distinguishedhistory over almost three decades of bringing analogs

to the geoscience community, and this, the 28th, aspiresto follow in that tradition.

The original aim of this Research Conferencewas to expand a little further the pool of analogs wework with in a particular area: that of the developmentand production of hydrocarbon accumulations hostedin deep-water rocks. There was a specific intent to fol-low up on the GCSSEPM Research Conferences of1994 (Submarine Fans and Turbidite Systems,Sequence Stratigraphy, Reservoir Architecture and Pro-duction Characteristics - Gulf of Mexico andInternational) and 2000 (Petroleum Systems of Diver-gent Continental Margin Basins), both of whichintroduced new fields and new deep-water concepts.Specifically, it was hoped that we could persuade theauthors of some of the classic papers on Gulf of Mex-ico and other worldwide deep-water fields introducedas discoveries or early producers in those conferencesto return to present on how their early predictions hadpanned out, and how their babies had grown up. Weeven hoped to inveigle some engineers into joining into share with us how their geoscience colleaguesworked with them to resolve the growing pains. It wasa deliberate attempt to tease out a more holistic pictureof the producing reservoir than is often found in thetrade journals of either geoscience, which as often asnot feature “mere” static description; or engineering,which often emphasize analytical mechanics over caus-ative geometry.

Alas, as the Scottish Bard had it, “the best laidplans o’ mice and men gang aft awry,” and that grandscheme has been thwarted by a number of realities thatbecame apparent as we solicited help from around theindustry. The principal culprit, it seems, is a simplelack of time on the part of most of our professional col-leagues. There is no denying that putting together apresentation of any sort for a 30 to 40 minute slot at aconference is both daunting and time-consum-ing…facts to be gathered and checked, co-authors to beconsidered, drafts and drafts edited and honed. Add tothat the requirement for a full-blown written paper (anda poster if you please!) and most people living a regular24-hour work-a-day life find it very difficult to getthere. When to this one adds the measure of corporaterigor that accompanies most “permission to publish”processes, the number of conferences that most of usreceive solicitations to attend and publish at, and thenumber of journals also vying for our attention, I sup-pose it is not surprising that it was an uphill struggle tofind the requisite willing volunteers. In spite of the fact

iv Program and Abstracts

that, dammit, this conference was a really good ideathat ought to have had everybody clamoring to join in!!

So, we backed off a little from the original granddesign, and have followed a path similar to the 1994and 2000 meetings, providing you with a smorgasbordof new analogs and new concepts, providing both thelatest from some newly producing fields, and some newand exciting ideas from some of our academic col-leagues who have been helping us to interpret ourreservoirs for many years. Although we have not hadthe pleasure of visiting with some old friends, thepapers on Holstein and Schiehallion in particularcleave closely to the spirit of the original intent.

The opening keynote address, from John Farrellyof BP, provides an overview of the lesson that is reiter-ated in many of the papers that follow: the successfuldevelopment of deep-water fields depends on planning,data collection and interpretation, working in an inte-grated fashion and, yes, selecting and utilizing theappropriate analogs. This theme of the importance ofchoosing the correct analog, specifically the correctoutcrop analog, is also pursued by David Stanbrook ofMaersk Oil & Gas. He and a number of co-authors alsoprovide examples of how outcrop analogs can be usedto resolve and understand the seismic responses of anumber of reservoir geometries through synthetic seis-mic modeling. The synthesis of analog studies toprovide a more statistical view of deep-water reservoirbehavior is presented by Cossey and Studlick.

The original challenge of an introduction to somenew fields and new concepts has been admirably takenup by authors presenting papers from both the Gulf ofMexico and Western Australia.

Form the Gulf of Mexico, Allen Mattis (Total)describes the development history of one of the newestsubsalt discoveries at Tahiti, soon to come on produc-tion. A little further along the reservoir life-cycle,colleagues from Australia cover the recently-inaugu-rated Stybarrow and Enfield oil fields and the large gasstatic resource at Scarborough. In the Enfield case, Meeand Meckel (Woodside Petroleum) provide a thoroughdescription of a slope turbidite field that was recog-nized from early in its development history as likely tobe a challenging resource to develop.1 The understand-ing of the field has been enhanced by the acquisition ofa 4D seismic program that, even in its early stages, hasyielded considerable fruit in terms of understanding

and being able to predict the behavior of the reservoir.In a case history of the adjacent Stybarrow Field, Hillet al. (BHP Billiton Petroleum) describe the appraisaland development history of another slope turbiditeaccumulation, including a brief description of the char-acterization of the reservoir through a stochasticinversion. This theme is taken up again in more detailin the paper on Stybarrow and Scarborough by O’Hal-loran et al. (BHP Billiton Petroleum)

The theme of “learning during early develop-ment” is also taken up in papers on two further fieldsearly in their production history. Wiseman et al. (BP)discuss the Holstein field, a supra-salt accumulation inthe Gulf of Mexico where an understanding of earlyproduction behaviour provided vital clues to constrainthe rebuilding of the initial reservoir model and for-ward planning of the ongoing development program. Asimilar story of complexity better defined during earlyproduction and the development of more sophisticatedmodels is told by Taylor et al. (BG) for the SapphireField in the Nile Delta. Moving on down the asset pro-ducing life, Davey et al. (BP) describe the “middleage” of the giant West-of-Shetland Schiehallion Fieldin the UK. This is a logical follow-on to the descrip-tions of Stybarrow, Enfield and Holstein, describing acase where the “easy oil” has been accessed, and con-tinued success depends on an increasinglysophisticated understanding of the interaction of pres-sure behaviour, geological complexity and fluidmovement.

Somewhat more theoretical studies of reservoircomplexity and how it can be described and accountedare presented in papers by McCaffrey et al. (U Leeds)describing the complex mass flow reservoirs of theCretaceous Britannia Sandstone of the North Sea, andHaughton et al. (UC Dublin) who cover similar grounddescribing the necessity to understand the context ofreservoir deposition in a basin, and how the geometryof any given reservoir is controlled ultimately by thebehaviour of the flows that deposited it.

Returning to the use of outcrop analogs to pro-vide both a contextual framework and a geometricdescription for understanding deep-water reservoirs,keynote presentations by Gardner et al. (MontanaState) and Bernhardt et al. (Stanford) discuss outcropdata from West Texas and Chile, respectively. The lat-ter paper describes the geometrical evolution of aforeland succession with associated facies evolutionand analog scales. The paper by Gardner et al. providesa synthesis of many years of work on the classicBrushy Canyon outcrops, drawing the work together to

1. Unfortunately, a permissions problem resulted in the last-minute withdrawal of the full paper and presentation aswe went to press. The abstract, with references for thosewishing more detail, is included at the end of this volume.

Answering the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation v

describe a new hierarchical stratigraphic model that canbe used as a framework for the prediction of sedimen-tary architecture…bringing us back to the openingdiscussion of the contextual paradigms within whichwe use our analogs to make predictions. The paper byLerch et al. (BHP Billiton Petroleum) applies this newstratigraphic model to an area in the Gulf of Mexico.

In summary, the 28th GCSSEPM Research Con-ference follows proudly in the footsteps of those thathave gone before, not so much standing on their shoul-ders but working diligently to add an extra increment tothe termite mound, contributing to the stock of analogsthat help all of us do our work better, providing somemore rocks without which none of us can hope tobecome better geoscientists.

As convener of the conference, I would just loveto take credit for all that lays before you. Modesty,integrity, and most of all the likelihood that I will belynched by the myriad of people who have helpedalong the way, however, prevent me from doing so.First and foremost, I express my gratitude to theauthors of the eighteen papers presented herein. Theyhave, collectively, produced a cohesive and informativecollection of new analogs and ideas that will be of greatvalue to their peers all around the industry. Some ofthem (OK, one of them) even managed to do so by theoriginal deadline. I take my hat off to their profession-alism and willingness to share their knowledge,notwithstanding the obstacles of time, corporateapprovals, and competing venues. My thanks also to

the Trustees of the Foundation, particularly ChairmanNorman Rosen, who supported the theme from the get-go, displayed considerable faith in our ability to deliveron the promise even when it looked as if there wouldn’tbe enough “volunteers” to fill the program, and whohas been a great support in the editing of the papers thatmake up the final volume. Norm…I apologize unre-servedly for the odd occasion when the combination ofthe day job, the travel schedule, and my sublime con-viction that it would all be alright on the night causedthe teeniest bit of friction to creep into our dialog. Myfriends and colleagues Deb Pfeiffer (BHP Billiton) andSam Johnson (BP) also provided editorial support, andmy thanks also are due to Paul Weimer of UC Boulderand Mike Sweet of ExxonMobil and Andy Pulham, allof whom worked hard shaking the bushes to drum uppapers. Honorable mention is also due to Brad Prather(whose paper made a gallant dash through the firstquarter mile, only to fall at the first corporate approvalfence) and Tim Garfield, both of whom attempted invain to squeeze papers from the stone of their respec-tive employers. My considerable gratitude also goes toGail Bergan of Bergan et al., Inc., who has worked farharder, far longer, and much closer to the meeting thanshe should have had to while compiling the abstractsand published volume.

However, gentle reader, you’re here to enjoy theconference, not to read history. Go forth, listen, learn,and most of all enjoy adding our offering to your stockof analog stories. You’ll be the better geoscientist for it.

Kevin Schofield

vi Program and Abstracts



28th Annual Gulf Coast Section SEPM FoundationBob F. Perkins Research Conference

Houston Marriott WestchaseHouston, Texas

December 7–9, 2008

Program

Sunday, December 7

4:00–6:00 p.m. Registration (Grand Foyer) and Poster Setup (Grand Pavilion)6:00–8:00 p.m. Welcome Reception and Poster Preview (Grand Pavilion)

Monday, December 8

7:00 a.m. Continuous Registration (Grand Foyer)7:45 Welcome remarks, Mike Nault (Chair of the Board of Trustees, GCSSEPM Foundation)

(Grand Pavilion)

Session 1: Monday MorningCharacterizing and Dealing with Uncertainty

8:00 Introductory remarks, Kevin Schofield (Conference Convenor)

Keynote Address

8:10 ................. Preparing for Uncertainty: Why Front End Loading Matters in Predicting Reservoir BehaviourFarrelly, John

9:00 ................. Multi-Disciplinary Reservoir Description to Characterize Connectivity in a Complex Minibasin Fill—An Integrated Approach at Holstein Field

Wiseman, Terry R.; Wagerle, Roger; Ballin, Paulo R.; Bump, Alex; McCaslin, Neil F. and Lederer, Mark

9:40 ................. Facies Characteristics in a Semi-Confined Basin: From High Net-to-Gross Channelized Sheets to Lower Net-to-Gross Onlap Margins: Grand Coyer Basin, SE France

Stanbrook, David A., and Pringle, Jamie K.

10:20 Coffee

Answering the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation vii

Session 1: Monday Morning (Cont.)Characterizing and Dealing with Uncertainty

10:40 ............... Impact of Multiple Scales of Remobilization on Deep Marine Clastic Reservoir Architecture: The Aptian Britannia Sandstone Formation, North Sea

McCaffrey, William D.; Eggenhuisen, Joris; Haughton, Peter D.W.; Butler, Robert W.H.; Barker, Simon P.; Del Pino Sanchez, Adriana; Archer, Stuart; Colleran, John; Hakes, Bill; Moore, Ian; and Hailwood, Ernie

11:20 ............... Reducing Time and Risk in Reservoir Modeling by Avoiding Pitfalls in Outcrop Analogue ChoiceStanbrook, David

12:00–1:30: Lunch

Session 2: Monday AfternoonGeneral Models and Statistical Analysis

Keynote Address

1:30 p.m. ........ Stratigraphic Models for Deepwater Sedimentary SystemsGardner, Michael H.; Borer, James M. ; Romans, Brian W. ; Baptista, Noelia; Kling, Erik K.; Melick, Jesse J.; Wagerle, Roger; and Carr, Mary M.

2:20 ................. Creation and Application of a 3D Synthetic Stratigraphic and Seismic Model Using Systematic Stratigraphic Principles and Realistic Rock Properties

Lerch, Chris; Thompson, T.; Apps, Gill; Hayes, Ian; Leishman, Markus; Gardner, Michael H.; Stoughton, Dean; Glinsky, Mike; and White, Chris

3:00 ................. Characteristics of Worldwide Hydrocarbon Discoveries and Fields in Deep-Water DepositsCossey, Stephen P.J., and Studlick, Joseph R.J.

3:40–4:00: Coffee

Session 3: Monday AfternoonUse of Forward Models for Characterization

4:00 ................. Resolving Deep-Water Stratigraphic Traps: Forward Seismic Modeling of a Turbidite Onlap: Montagne de Chalufy, Gres D’Annot Formation, SE France

Stanbrook, David A.; Pringle, Jamie K.; Elliott, Trevor; Clarke, Julian D., and Gardiner, Andrew

4:40 ................. Resolving Deep-Water Channel Architectures: High Resolution Forward Seismic Modeling of Tur-bidite Systems, Ainsa II Channel, Campodarbe Group, Northern Spain

Pringle, Jamie K.; Stanbrook, David; and Clarke, Julian D.

5:30–8:00: Open Poster Session and Buffet Supper

8:00 Authors remove posters; contractor will start removing display boards at 8:15 p.m.

viii Program and Abstracts

Tuesday, December 9

Session 4: Tuesday MorningTaking Care of Business: Analogues and Characterizing Channel and Slope Reservoirs

8:30 a.m. Introductory remarks, Kevin Schofield

Keynote Address

8:40 ................. The Multi-Stage Evolution of an Elongate Submarine Fan Through an Axial Channel Belt to a Pro-grading Slope System: The Deep- to Shallow-Marine Fill of the Magallanes Basin, Chile

Bernhardt, Anne; Jobe, Zane R.; Lowe, Donald

9:30 ................. Sapphire: Not Another Layer CakeTaylor, Katy; Folefac, Alex; Elsherbiny, Ahmed S.; Abonaem, Khaled; Fathy, Alaa, and Mohammed, Rehab E.

10:10 Coffee

10:50 ............... Development of a Slope Turbidite Reservoir: A Case History from the Stybarrow Field, Western Australia

Hill, Robin; O’Halloran, Gerard; Elliott, Alison; Locke, Mark; Napalowski, Ralf, and Croft, Marion

11:20 ............... Managing and Mitigating the Midlife Stage of the Giant Schiehallion field, Tertiary Deepwater, West of Shetlands, UK

Davey, Simon; Macdonald, Chris; Martin, Karen; MacGregor, Alan; Fletcher, John; Davies, Merv, and Pettigrew, Sara

11:50 ............... Integration of Model-Based Seismic Inversion (DELIVERY) in the Stratigraphic Interpretation of Turbidite Reservoirs from the Stybarrow Field and Scarborough Discovery, Western Australia

O’Halloran, Gerard; Hill, Robin; Woodall, Mark; Goody, Angus, and Glinsky, Mike

12:20–1:45: Lunch

Session 5: Tuesday AfternoonTaking Care of Business: Analogues and Characterizing Lower Slope and Basin-Floor Reservoirs

Keynote Address

1:45 p.m. ........ Sediment Gravity Flow Deposits and Bed-Scale Heterogeneity—Lessons from North Sea FieldsHaughton, Peter D.W.; McCaffrey, William D.; Davis, C., and Barker, Simon P.

2:35 ................. Geological Challenges in Reservoir Modeling, Tahiti Field, Green Canyon 596/640, Gulf of Mexico

Mattis, Allen F.

3:15 Concluding remarks, Kevin Schofield

Author Index ....................................................................................................................................... A-1

Answering the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation ix

GCSSEPM Foundation

Trustees and Executive DirectorMichael J. Nault (Chairman)Applied BiostratigraphixHouston, Texas

Paul Weimer University of ColoradoBoulder, Colorado

Michael J. StyzenShell International E&P Inc.Houston, Texas

Anthony D’AgostinoOmni LaboratoriesHouston, Texas

Norman C. Rosen, Executive DirectorNCR & AssociatesHouston, Texas

Executive Council

PresidentJanok P. BhattacharyaUniversity of HoustonHouston, Texas

President ElectJohn WagnerUniversity of HoustonHouston, Texas

Vice PresidentJohn SneddenExxonMobil Upstream ResearchHouston, Texas

SecretaryLana CzerniakowskiMurphy E&P CompanyHouston, Texas

TreasurerRamón TreviñoBureau of Economic GeologyAustin, Texas

Past-PresidentKevin SchofieldBHP Billiton Petroleum (Americas) Inc.Houston, Texas

Audio-Visual and Poster CommitteeMichael J. Nault (Chairman)Applied Biostratigraphix

Arden CallenderApplied Biostratigraphix

Program Advisory Committee Co-ChairmenKevin SchofieldBHP Billiton Petroleum

Deborah PfeifferBHP Billiton Petroleum

Sam JohnsonBP

Ciaran O’ByrneShell

Mike SweetExxonMobil

Alan ClareApache Corporation

Chuck SteltingChevron

Paul WeimerUniversity of Colorado, Boulder

x Program and Abstracts

Contributors to the GCSSEPM Foundation

Sponsorship CategoriesPlease accept an invitation from the GCSSEPM Section and Foundation to support Geological and Geophysical

Staff and Graduate Student Education in Advanced Applications of Geological Research to Practical Problems ofExploration, Production, and Development Geology.

The GCSSEPM Foundation is not part of the SEPM Foundation. In order to keep our conferences priced at a lowlevel and to provide funding for university staff projects and graduate scholarships, we must have industry support.The GCSSEPM Foundation provides several categories of sponsorship. In addition, you may specify, if you wish,that your donation be applied to Staff support, Graduate support, or support of our Conferences. Please take amoment and review our sponsor categories for 2008, as well as our current and past sponsors. In addition, we askthat you visit our sponsors’ Web sites by clicking on their logo or name. Thank you for your support.

Corporate Sponsorships

Diamond($15,000 or more)

Platinum($10,000 to $14,999)

Gold($6,000 to $9,999)

Silver($4,000 to $5,999)

Bronze($2,000 to $3,999)

Patron($1000 to $1,999)

Individuals & Sole Proprietorships

Diamond($3,000 or more)

Platinum($2,000 to $2,999)

Gold($1,000 to $1,999)

Silver($500 to $999)

Bronze($300 to $499)

Patron($100 to $299)

Sponsor AcknowledgmentFor 2008, all sponsors will be prominently acknowledged on a special page inserted in the 2008 and 2009

Conference Abstracts volume and CDs, and with large placards strategically placed throughout the meeting areasduring these conferences.

Corporate-level Diamond sponsors will be acknowledged by having their logo displayed on the back cover of thejewel case for the Conference CD. Corporate level Platinum sponsors will be acknowledged by having their logoplaced in the front matter of the Program & Abstracts volume. All contributions used for scholarships and/or grantswill be given with acknowledgment of source.

In addition to the recognition provided to our sponsors in GCSSEPM publications, we proudly provide a link toour sponsors’ Web site. Just click on their logo or name to visit respective GCSSEPM sponsors.

The GCSSEPM Foundation is a 501(c)(3) exempt organization. Contributions to it are tax deductible ascharitable gifts and contributions.

For additional information about making a donation as a sponsor or patron, please contact Dr. Norman C. Rosen,Executive Director, GCSSEPM Foundation, 2719 S. Southern Oaks Drive, Houston, TX 77068-2610. Telephone(voice or fax) 281-586-0833 or e-mail at [email protected].

mailto:[email protected]

Answering the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation xi

2008 Sponsors

Individuals and Sole Proprietorships

Diamond

Platinum

Gold

Silver

Bronze

Patron

Silver Ed Picou Michael J. Nault Michael J. Styzen

http://www.conocophillips.com

http://www.devonenergy.com

http://www.shell.com

http://www.bhpbilliton.com

http://www.slb.com

http://www.statoilhydro.com

http://www.nexenenergy.com

http://www.murphyoilcorp.com

http://www.nautilusworld.com

xii Program and Abstracts

2007 Sponsors

Corporate Sponsorships

Individuals and Sole Proprietorships

Diamond

Platinum

Gold

Silver

Gold

Silver Ed Picou Michael J. Nault

Bronze Nancy Engelhardt-Moore

http://www.tectonicanalysis.com

http://www.devonenergy.com

http://www.shell.com

http://www.statoil.com

http://www.chevron.com

http://www.bhpbilliton.com

http://www.conocophillips.com

http://www.eogresources.com

Answering the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation xiii

Credits

CD ROM Design and Publishing by

Rockport, Texaswww.bergan.com

Cover ImageThe cover image chosen for this year’s conference is Figure 4 from Stanbrook et al.: “Resolving Deep-Water

Stratigraphic Traps: Forward Seismic Modeling of a Turbidite Onlap; Montagne de Chalufy, Grès d'AnnotFormation, Southeast France.”

http://bergan.com

http://www.bergan.com

xiv Program and Abstracts

Answering the Challenges of Production from DW Reservoirs: Analogues and Case Histories to Aid a New Generation 1

Preparing for Uncertainty: Why Front End Loading Matters in Predicting Reservoir Behaviour

Farrelly, John

AbstractReservoir performance prediction begins in the

earliest phases of opportunity selection. In the Gulf ofMexico doing all things possible to inform and com-pensate for inherent subsurface uncertainty and relatedresource, rate and profile risks is particularly important.As we move to increasingly challenging developments,many key subsurface uncertainties will persist wellafter production commences. This is the result of com-plex petroleum systems, expense involved in collectingappraisal data, lack of dynamic data, and limited avail-ability of robust production analogues. At a high level,there are three themes or focus areas that help shapeperformance prediction and address uncertaintytherein.

Firstly, the right level of front end loading at eachstep from exploration idea to production is necessary.This begins with thinking about “developability”before exploring. Beyond volumes, what are the rate,

well density, and overall cost ranges anticipated? Beingdeeply considerate of the value of information to beobtained in exploration and appraisal work is key toinform these parameters.

Next, analogue choice is critical and must gobeyond rock properties to whole rock and fluid systemanalogues. Asking why we want an analogue reallymatters. Are there limits to the analogue relative to thediagenetic and structural overprints that may beanticipated?

The third theme is working in an integrated fash-ion to build flexibility into chosen developmentconcepts.

This presentation will discuss how addressingthese themes enables uncertainty to be more efficientlyreduced and mitigated using examples from a numberof Gulf of Mexico reservoirs.

2 Program and Abstracts

Multidisciplinary Reservoir Description to Characterize Connectivity in a Complex Minibasin Fill—An Integrated Approach at Holstein Field

Wiseman, Terry R. Wagerle, RogerBallin, Paulo R.Bump, AlexMcCaslin, Neil F. Lederer, Mark

AbstractThe Holstein reservoirs comprise a series of

stacked Lower to Middle Pliocene turbidite sands withthe field formed structurally by a large, steep, south-easterly dipping, monoclinal structure. Oil columnheights exceed 2500 ft. Stratigraphic and structuralcomplexity was documented through careful intra-res-ervoir mapping, seismic facies analysis and structuralinterpretations integrated with static and dynamic pres-sure data (build-up and interference tests). Theintegrated geologic analysis revises the existing Hol-stein geologic model for improved developmentplanning and early production management.

The geological model developed at sanctiondescribed the unconsolidated reservoir sands as beingdeposited in a ponded, intraslope salt basin dominatedby thick, high energy amalgamated reservoirs withinternal homogeneity and excellent connectivity. Earlyperformance suggested heterogeneities are more com-plex than originally envisaged. The reservoir

architecture elements comprise sandy sheets and chan-nels that shingle to form genetically related reservoirs.Static and dynamic pressure data, build-up tests, andinterference tests suggest baffling between geobodiesand pressure-isolated compartments between someshingles. Post-depositional modification of the reser-voir further complicates well performance by removingreservoir entirely or reducing thickness. In addition, astructural overprint creates deformation bands whichappear to reduce well productivity through reduction ofeffective permeability in the structurally steepest seg-ment of the field.

A revised understanding of reservoir heterogene-ity calibrated with dynamic data has allowed a greaterunderstanding of variations in well performance. On afield scale the characterizations have been incorporatedinto a re-build of the reservoir model, which has cre-ated greater confidence in the depletion plan tooptimize recovery.


Facies Characteristics in a Semi-Confined Basin: From High Net-to-Gross Channelized Sheets to Lower Net-to-Gross Onlap Margins: Grand Coyer Basin, SE France

Stanbrook, David A.Pringle, Jamie K.

AbstractCommon stratigraphic-trap reservoirs in the Gulf

of Mexico and along the margins of the Atlantic arefound within channelized (e.g. Tahoe) or basin marginsettings (e.g. Auger, Mars). These are frequently withinsmall, structurally controlled and topographically com-plex ‘fill & spill’ mini-basins; most often in salt-provinces. Both high net:gross channel and lowernet:gross basin-margin environments occur concur-rently in most basins and deciphering the lateral anddistal relationships between these environments is keyto understanding reservoir connectivity.

The Grand Coyer remnant (Grès d’Annot, SEFrance) demonstrates lateral and distal facies changesin a confined basin with complex paleotopography.Within the basin a relatively thin-bedded unit, the Mar-nes Brunes Inférieures (MBI) is interpreted as a distal

and lateral equivalent of the thick-bedded Grèsd’Annot (Stanbrook & Clark 2004). The MBI repre-sents deposition away from the main axis of flowwhich is represented by the Grès d’Annot.

The finer grained facies of the MBI is shown topre-date as well as to intercalate with the highernet:gross sections the Grès d’Annot in a lateral and dis-tal sense. Also the bedding of the MBI is shown toonlap the underlying paleotopography, with highernet:gross Grès d’Annot, in turn, onlapping the MBI;these bedding discordances are often associated withslumping. The intercalation and bedding-discordancehas implications for hydrocarbon charge, seal and lat-eral distal connectivity. Multiple examples of, and therelationships between, these facies are shown.

Schematic representation of erosional relationships between channelized, high net:gross Grès d’Annot and the thinnerbedded Marnes Brunes Inférieures; one of several variations in facies relationships induced by complex topography.


Impact of Multiple Scales of Remobilization on Deep Marine Clastic Reservoir Architecture: The Aptian Britannia Sandstone Formation, North Sea

McCaffrey, William D.Eggenhuisen, JorisHaughton, Peter D.W.Butler, Robert W.H.Barker, Simon P.Del Pino Sanchez, Adriana

Archer, Stuart

Colleran, John

Hakes, Bill

Moore, Ian

Hailwood, Ernie

AbstractThe Britannia Sandstone Formation in the Outer

Witch Ground Graben of the North Sea comprisesUpper Aptian deep-water sandstones. It has beenextensively drilled and cored on and around the Britan-nia gas condensate field. The Britannia reservoirsection thins and pinches out against a paleoslopeformed by the Fladen Ground Spur to the North. In thepast, the reservoir has been informally subdivided intoa series of numbered reservoir zones, largely guided bybiostratigraphy. On this basis, correlation within thelower half of the reservoir (sub zone 40) is extremelycomplex, whereas the upper half is broadly sheet-formand coherent. However, aspects of reservoir perfor-mance have proven difficult to reconcile with thisgeometric model - but these can now be related toremobilization effects at a variety of scales linked toinstability associated with the confining Fladen Groundslope. Until recently, the lower half of the reservoir wasthought to represent a sequence of in-situ turbidite bedsalternating with a series of moderate-scale debris flowdeposits. However, detailed mapping in the Platformarea of the field has shown that whilst wells in theNorth-west preserve a lower section that is intact within-situ and correlatable sandstones, sections to the Westand South-east are involved in large scale mass trans-port, and the sandstones are either disconnected blocksor have been homogenized and degraded by mixing

with clay prone lithologies during remobilization. Pre-vious zonal picks lie in or on the margins of debritematrix sections between blocks. In the upper reservoirsection, sheet sandstones have locally been duplicated,thinned or even excised by post-depositional sliding.One failure event (separating the zones 45 and 50 sheetsandstones) is associated with the down-dip emplace-ment of a thick olistostrome unit and debris flow thatremoved large sections of the underlying sandstonestratigraphy and emplaced large rafted blocks up to 10m in thickness. The combined effects of this remobili-zation created an irregular base-of-slope topographywith local relief estimated to exceed 15 m. The nextturbidity current to enter the basin produced a depositthat essentially compensated for the preceding masstransport complex, with significant impact on modelednet-to-gross distribution. On a smaller scale within theupper reservoir section, syndepositional remobiliza-tion is thought to have caused local bed shearing,folding and inversion. A Remobilization Index hasbeen applied that shows that the slope-adjacent sectionsare more prone to remobilization than slope-distal sec-tions, and that the length scale of this variation can bedefined. Limited reservoir production data suggest thatreservoir performance may be in inversely-correlatedwith the degree of bed disaggregation identified byhigh indices of remobilization.


Reducing Time and Risk in Reservoir Modeling by Avoiding Pitfalls in Outcrop Analogue Choice

Stanbrook, David

AbstractGeoscientists and engineers routinely apply out-

crop analogues as an integral part of constructinggeological models, and their use has become a commonand useful tool in petroleum geoscience. Reservoir ana-logues are used at every stage of field life, fromprospect development to maximizing returns in maturefields.

But how do we choose the correct outcrop ana-logue? For any given sedimentological environmentthere are dozens of well documented outcrops that maybe used. Geoscientists and engineers must not onlyselect analogues appropriate to the reservoir but con-sider the scale of the outcrop compared to seismic,petrophysical and other tools which may vary widelyfrom one another. Combine the outcrop variables withsub-surface variables and the possibilities are almostlimitless. Without investing a disproportionate amountof time in researching the multitude of outcrops andtheir characteristics, asset teams must find a way to col-late, assess and distil key information. To collate

detailed geometrical and architectural information onall, or even just major, outcrop types is time extremelytime consuming.

Inclusion or elimination of analogues can beachieved by simultaneous evaluation of sub-surfaceand outcrop analogue data from a depositional systemmodel standpoint. This allows the geologist to mapwhat is known about their prospect onto what is knownabout the outcrops. A well selected depositional systemmodel acts as the bridge between the two allowing ini-tial selection, and more importantly, de-election ofanalogues.

An example of a systematic and consistentapproach to outcrop analogue choice is given. Throughthe use of depositional models it is possible to makecritically derived choices about which analogues to use.It also allows the proper elimination of which ana-logues not to use, thus freeing time to focus on thoseanalogues that are most relevant.


Stratigraphic Models for Deepwater Sedimentary Systems

Gardner, Michael H.Borer, James M.Romans, Brian W.Baptista, Noelia

Kling, Erik K.Melick, Jesse J.Wagerle, RogerCarr, Mary M.

Abstract

Stratigraphic models predict sedimentary archi-tecture. Prediction requires understanding systems insufficient detail to permit identification and quantifica-tion of the process-response relationships that definethem. For deepwater sedimentary systems this includesunderstanding the controls on sedimentary bodyemplacement, the geomorphic hierarchy of body types,the process linkage between the channel fill and flank-ing deposits, and how depositing flows evolve andtransform across shelf-to-basin profiles. Because thick-ness, lithology and sedimentary body type all varythrough a diachronous episode of deepwater sedimen-tation, these changes can be used to define phases insystem evolution. These sedimentation phases reflectenergy changes within the sedimentary system, whichare driven by both external (allogenic) and internal(autogenic) controls.

Shelf-to-basin studies of the Brushy Canyon For-mation demonstrate that the more complete basinalrecord correlates to a fragmented shelf record, with thisincongruity impacting recognition of allogenic forcing.As the ultimate sediment sink, the external controls arebest resolved from the deepwater record, but internalchanges in local gradient and topography also impactsedimentation. This can make it difficult to differenti-ate between external controls without completecharacterization of the basin. Despite these challenges,two stratigraphic models have been developed to pre-dict patterns of deepwater sedimentation. Thoughderived from Middle Permian Brushy Canyon cyclesmapped in outcrop and correlated across the DelawareBasin, the models have been tested against many othersystems and basins.

Tectonics and climate combine to modulate sedi-ment supply and sea level, which are considered theprincipal allogenic controls on sedimentation. Allo-genic controls moderate system energy during adiachronous episode of deepwater sedimentationdescribed by the phases of the AIGR (pronounced“Eiger,” after the Swiss mountain) stratigraphic model.

Unlike the phases of sea level change correlated insequence stratigraphy, the AIGR model emphasizesdeepwater system energy recorded in the basin. A com-plete AIGR cycle of sedimentation commences withthe Adjustment phase, which defines the important ini-tial conditions of profile gradient and topography. Thisphase can be represented by a surface, e.g., an uncon-formity, a mass transport event, or be recorded bylithology and/or architectural changes. The Initiation,Growth, and Retreat sedimentation phases representimportant depositional phases that record changes insystem energy, gradient, and sediment supply at multi-ple scales within a basin. These depositional phasescharacterize architectural and lithology changes andthickness distributions within a hierarchy of strati-graphic cycles.

Sedimentation generates topography, whichshifts deposition laterally and transforms active sedi-mentation sites into inactive ones. This repetitivepattern of sedimentation generates cyclic facies succes-sions of limited extent, which are referred to asautogenic cycles. In deepwater systems autogeniccycles can be generated by the retrogressive failure ofslumps, by the lateral offset and compensational stack-ing of lobes, by channel switching, migration andavulsion, and by longitudinal translation of the chan-nel-lobe transition zone.

The architecture of channel and channel-relatedbodies reflects migration patterns of the channel-lobetransition zone described by the Build-Cut-Fill-Spill(BCFS) stratigraphic model. These sedimentationphases can produce a sheet-channel-sheet architecturethat varies with longitudinal profile position (gradient)and degree of confinement. Channel-fill, channel-flankand lobe sedimentary bodies represent building blocksthat vary in proportion and arrangement in each phase.The BCFS model for submarine channels is embeddedwithin the AIGR basin model and together they empha-size the correlation of a hierarchy of internally andexternally generated stratigraphic cycles.


The AIGR and BCFS models correlate strati-graphic cyclicity to sedimentary architecture. Theydescribe the systematic increase and decrease in sedi-mentation energy recorded in stratigraphy. The modelsare flexible because not all four energy phases definedin each model needs to be present for its application. In

their complete form, the models recognize four sedi-mentation phases that generate distinct styles ofsedimentary architecture and that may repeat and canbe linked to changes in accommodation space and sedi-ment flux.


Creation and Application of a 3D Synthetic Stratigraphic and Seismic Model Using Systematic Stratigraphic Principles and Realistic Rock Properties

Lerch, ChrisThompson, T.Apps, GillHayes, IanLeishman, Markus

Gardner, Michael H.

Stoughton, Dean

Glinsky, Mike

White, Chris

Abstract

Datasets from hydrocarbon discoveries in deep-water stratigraphy in the Gulf of Mexico have served asthe basis for the creation of a 3D synthetic stratigraphicand seismic model. Datasets included thick verticalsections of turbidite stratigraphy and good quality 3Dseismic images. Creation of the model served as aquantitative way to apply systematic stratigraphic prin-ciples derived from outcrop and subsurface studies, aswell as a way to predict variation in local reservoirquality and properties. In addition this work was able tomeasure the ability of seismic data to detect such varia-tions. In this case the seismic detectability wasrelatively subtle.

The full clastic system at these discoveriesencompasses 15-25 Ma and equates roughly to one sec-ond-order sequence stratigraphic cycle. This intervalhas been split into three third order cycles, each c.2 to10 Ma. Seismic character and well log analysis of theturbidite system defined vertical and lateral variation inreservoir geometries (for example, axial fairway versuslobe versus lobe fringe patterns) and properties (such asbed thickness, net/gross, sorting, and permeability). Ageneral stratigraphic framework and facies model fromthe Brushy Canyon Slope and Basin industry consor-tium was applied to the dataset to predict the shape andsize of third through fifth order stratigraphic bodies,and the evolutionary variation of such bodies. Thisstratigraphic model, known as the “AIGR” model,characterizes the evolution of a stratigraphic systemthrough an initial slope adjustment phase, followed byinitiation, growth, and retreat phases of a turbidite sys-tem itself.

The basic and easily modifiable building blockused in this synthetic model creation was a “channel-levee” pattern where the length and width of a centralchannel element, the length and width of flanking leveeelements, and the size of the combined pattern was var-ied. A sheet element was a special case of this patternwhere the “channel” was very wide and long and theflanking levees non-existent. The automation of bodynumber, placement, size, shape, and reservoir propertyassignment was facilitated by a driving parametercalled the “retreat index”. This index parameter was setto vary in a cyclic fashion within the context of thelower-order system initiation/growth/retreat cycle,thereby driving systematic variation in all the otherparameters.

The second to third order description of themodel in three dimensions was constrained by the pri-mary seismic markers mapped on the actual seismicdata and penetrated by the well control through the tur-bidite system. Depth and time models were built intandem, using appropriate sub-regional time-depthfunctions. Fourth and fifth-order body placement wasdone by allowing randomly generated body centersconfined by a probability function defined by isochorethickness of the interval being populated.

Following creation of the synthetic model geom-etry and property variation a number of syntheticseismic volumes, derived volumes, and attributes werecalculated. In addition many of the volumes werestratigraphically flattened to allow easier display oflayer-based lateral variation.


Characteristics of Worldwide Hydrocarbon Discoveries and Fields in Deep-Water Deposits

Cossey, Stephen P.J.Studlick, Joseph R.J.

Abstract In early 2006, a study of the characteristics of

deep-water fields and reservoirs was completed by theauthors (Cossey and Studlick, 2007). Since that time,73 discoveries have been added to the worldwideinventory of deep-water fields. Most of the newer dis-coveries have been made in Gulf of Mexico, but othernotable discoveries have been made in China, India,Brazil, Mexico and West Africa. This paper providesan updated set of statistics, plots and characteristics ofthe 945 deep-water discoveries around the world and acomparison with the conclusions from a similar studycompleted almost 3 years ago.

More than 945 discoveries with total reserves>150 billion barrels of oil equivalent (BBOE) havebeen made in deep water deposits. A rapid increase insuch discoveries began in the 1970s, corresponding to

the advent of exploration in the North Sea and the earlysuccesses in the Campos Basin of Brazil. Based on his-toric trends, 300 are expected this decade.

More than 84% of the discoveries are in offshorebasins. North America dominates the number of totaldiscoveries as well as reserves, but there are an increas-ing number of discoveries in Africa and Asia.Reservoir rocks range in age from Ordovician to Pleis-tocene. However, more than 90% of discovereis are inCretaceous or younger rocks. Passive margins havebeen the tectonic setting for most of these accumula-tions, and most are in slope depositional environments.Further statistics on hydrocarbons types, reservoirdrives, trap types, porosity, and hydrocarbon columnheights are presented from a database compiled byCossey and Associates Inc.


Resolving Deepwater Stratigraphic Traps: Forward Seismic Modeling of a Turbidite Onlap: Montagne de Chalufy, Gres D’Annot Formation, SE France

Stanbrook, David A.Pringle, Jamie K.Elliott, TrevorClarke, Julian D.Gardiner, Andrew

Abstract

The Gulf of Mexico and other salt/structuralprovinces are well known for stratigraphic traps withinup-dip deep-water clastic sequences within a basin fill.Understanding the stratigraphic relationship betweenthese sequences and underlying depositional slopes arecritical to understanding charge and seal. This relation-ship is hard to resolve seismically, particularly in saltprovinces where overlying salt-bodies may obscurefiner-scale relationships that are key to reservoir seal.Lack of seals below seismic-resolution may act aspotential ‘thief zones’ for hydrocarbons. In these cir-cumstances outcrop analogues can provide examples oftrue onlap relationships and aid understanding to whatthe seismic expression may be.

The Montagne de Chalufy is a spectacular, seis-mic-scale outcrop. The section has been fieldinvestigated, interpreted, digitized and modeled, togenerate forward seismic 2D sections. Three parame-ters were investigated: impedance contrast, model

detail and wavelet frequency. Typical velocity and den-sity values were taken from published producingreservoir data for observed lithologies.

Three seismic impedance scenarios were repre-sented: Plio-Pleistocene Gulf of Mexico, TertiaryNorth Sea and Jurassic North Sea. Two levels of modeldetail were investigated, i) a detailed model to test seis-mic resolution and, ii) a simple onlap model withoutstructural and sedimentary complexities. Two dominantRicker wavelet frequencies were chosen, 26 and 50 Hz.

Results show outcrop analogues of turbiditesandstone reservoirs may be usefully converted to for-ward seismic sections. Model sections generated fromhigh frequency wavelets allow interpretations thatalmost replicate detailed geological models. Grossarchitectures of massive, onlapping, turbidite sand-stones may still be resolved in low frequency seismicdatasets.

Forward seismic 2D section of the Montagne de Chalufy onlap section using Plio-Pleistocene Gulf of Mexico producingreservoir parameters.


Resolving Deepwater Channel Architectures: High Resolution Forward Seismic Modeling of Turbidite Systems, Ainsa II Channel, Campodarbe Group, Northern Spain.

Pringle, Jamie K.

Stanbrook, David

Clarke, Julian D.

Abstract

Deep-water channels are of common interest inhydrocarbon exploration, however internal architec-tures and overall net:gross can be hard to resolveseismically. Channel-fill may range from highnet:gross, back-stepping sheet-like geometries, multi-ple re-incisions to mass-transport complexes or passiveinfill. Interpreting this complexity is crucial in predict-ing reservoir fluid flow behavior. Seismic data areheavily relied upon for such interpretations. Outcropanalogues can provide examples of intra-channel geo-metric relationships and aid understanding of what theseismic expression may be.

The Ainsa II channel, Campodarbe Group, north-ern Spain is a spectacular exposure of slope conduits.The channel complex consists of five stacked channelunits, characterized by distinct internal architectures.Forward 2-D seismic sections have been generated toinvestigate the effect that different rock properties andseismic frequencies have on resolving the channelcomplex geological detail.

Three seismic impedance scenarios were repre-

sented: Plio-Pleistocene Gulf of Mexico, Tertiary

North Sea and Jurassic North Sea. A variety of domi-

nant frequencies were used to investigate seismic

resolution, representing those typically used for imag-

ing deep and shallow reservoirs. Gamma Ray logs

allow unit correlations and comparison to subsurface

examples.

Results show that seismic images generated from

low frequency wavelets (26Hz) do not resolve impor-

tant heterogeneities within the channel complex. 52Hz

sections suggest the target interval consists of stacked

channels, although channel units are resolved. At

78Hz, an interpretation close to the geological model is

achieved. Differing impedance contrast values have lit-

tle effect on geological interpretations at the high

signal:noise ratios used, although impedance values

from North Sea Jurassic reservoirs yield the highest

amplitudes in the synthetic sections.

Forward seismic 2D section of the Aina II channel complex using Plio-Pleistocene Gulf of Mexico producing reservoir

parameters.


The Multistage Evolution of an Elongate Submarine Fan Through an Axial Channel Belt to a Prograding Slope System: The Deep- to Shallow-Marine Fill of the Magallanes Basin, Chile

Bernhardt, AnneJobe, Zane R.Lowe, Donald

Abstract The late Mesozoic to early Tertiary Magallanes

foreland basin in southernmost Chile formed whenregional shortening related to the Andean orogenycaused the inversion of the earlier Rocas Verdes back-arc basin into a retroarc foreland basin during the LateJurassic. This inversion, the orogeny, and the onset ofdeep-water sedimentation is recorded by the ~1000 mthick Punta Barrosa Formation (Turonian-Coniacian)characterized by 40-150 cm-thick, generally medium-grained, tabular, turbiditic sandstone beds that alternatewith abundant shale, sandy slurry flow and debris flowdeposits. Sedimentation style changes during deposi-tion of the overlying Cerro Toro Formation (Coniacian-Campanian), which consists of thick successions ofthin-bedded mudstone and sandstone turbidites anddebris flow deposits interrupted by thick (up to 400 m)deep-water channel complexes. The channels are filledwith conglomeratic turbidity current deposits, con-glomeratic slurry flows, and thick-bedded turbiditesandstone. Sediment transport was dominated by a 5-8km wide axial channel belt with southward directedpaleocurrents. Potential tributary channel complexes,

possibly confined behind a local structural high, seemto have funneled sediment into the axial channel. Incontrast, the overlying Tres Pasos Formation (Campa-nian) comprises marine slope deposits that representsouthward progradation into the basin. Turbiditic sand-stones at the base of the formation are overlain byabundant mass transport deposits and fine-grained tur-biditic strata. Seafloor topography created by masstransport deposits affects the distribution of turbiditycurrents and their subsequent deposits. The transitionfrom slope deposits into shallow marine sediments isrecorded by the Dorotea Formation.

Due to its back-arc heritage, the Magallanesbasin remained within the deep-water environment for~ 15 Ma; however, depositional ages are still poorlyconstrained. Sedimentation style of the deep-waterbasin fill varies significantly throughout the three for-mations and the basin fill eventually shoals upward intoshallow marine and deltaic deposits. The sculpting ofthe outcrops by recent glaciation provides superb expo-sure of the basin fill, making the Magallanes basin anexcellent field area to study foreland basin evolution.


Sapphire: Not Another Layer Cake

Taylor, KatyFolefac, AlexElsherbiny, Ahmed S.

Abonaem, KhaledFathy, AlaaMohammed, Rehab E.

AbstractA key step in successful development planning

and subsequent reservoir management is the construc-tion of detailed geocellular models which capture theprinciple heterogeneities exhibited by the reservoirwhilst also addressing uncertainty. Current work flowswithin the off-shore Nile Delta, WDDM concessionrely heavily on the extraction of 3D seismic attributesto identify the main depositional elements and corre-lated to petrophysical properties.

The Lower Pliocene Sapphire Field is made upof a series of laterally extensive sheet-like reservoirsforming a stacked system of up to five pay intervalsover a 400m thick section. In this respect it is unlikealmost all of its WDDM counterparts which compriselargely canyon-confined sand-systems.

The pre-development, and largely simplisticlayer-cake view of this field, which could have beencarried through using the existing seismic workflows,has been re-assessed using data acquired during thedrilling of 8 development wells, the detailed seismicmapping at both layer and sandbody scale and an inte-grated G&G-reservoir engineering approach to thehistory matching phase.

The relatively thin-sheeted nature of the reservoirmeans that unlike other WDDM reservoirs seismicattribute volumes cannot be simply transformed to par-ticular reservoir parameters. The problem iscompounded by the stacked nature of the reservoirs,which introduces some degree of seismic masking, andthe presence of a gas chimney.

Seismic analysis at the sandbody-scale reveals ahigher level of complexity than evident in the mid–upper Pliocene canyon-fill reservoirs, with sand sheetshaving multiple origins (splays, 'lobes', single sandy/muddy channels) and channels being dominated byheterogeneous sheet and splay deposits. This deposi-tional complexity and the absence of clearly definedchannel, belt and overbank areas combined with theunpredictable relationship between average amplitudeand NHCPT has led to a more sedimentological drivenmodel. Although this appears to move away from thecurrent trend of simplifying reservoir models the heter-ogeneous nature of the Sapphire Field is born out byhistory matching and indicates that, certainly for reser-voirs like Sapphire, a comprehensive modelingapproach is appropriate.


Development of a Slope Turbidite Reservoir: A Case History From the Stybarrow Field, Western Australia

Hill, RobinO’Halloran, GerardElliott, Alison

Locke, MarkNapalowski, RalfCroft, Marion

Abstract Key subsurface challenges are faced in the devel-

opment of relatively thin slope turbidite reservoirscontaining biodegraded oil with little or no aquifer sup-port. Lateral reservoir variations have importantimplications for connectivity and therefore the optimaldrainage of such fields. This paper documents a multi-disciplinary approach applied during the appraisal anddevelopment of the Stybarrow Field, Western Austra-lia; examining how the integration of data on a varietyof scales, from seismic and well data, to geologicalanalogues and bed boundary resistivity modeling, hasenabled detailed 3D geological models to be generatedto estimate connectivity and oil recovery. Good reser-voir connectivity will be crucial for successful drainageand sweep of the field.

The Stybarrow Field is a moderately sized biode-graded oil accumulation reservoired in earlyCretaceous slope turbidite sandstones of the MacedonFormation in the Exmouth Sub-basin. Excellent quality

3D seismic has enabled attribute mapping and probabi-listic seismic inversion (DELIVERY) to be used toboth estimate the net sand distribution of the reservoirand facilitate optimal well placement. The reservoirinterval is extensively cored and comprises excellentquality, but poorly consolidated, sand rich turbiditesand grain flow sandstones within a variable net-to-gross interval up to 20m thick. The field lies in >800mwater depth and is being developed via an FPSO. Pres-sure support is required from field start-up via sub-seawater injection wells due to an expected lack of aquifersupport. Horizontal production wells with high produc-tivity indices are required for optimal drainage. Down-hole sand control is being provided by a combinationof open-hole gravel packs and sand screens.

The field began production in November 2008,four years and nine months from discovery and reachednameplate production capacity of 80,000bopd withinthree weeks.


Managing and Mitigating the Midlife Stage of the Giant Schiehallion field, Tertiary Deepwater, West of Shetlands, UK

Davey, SimonMacdonald, ChrisMartin, KarenMacGregor, Alan

Fletcher, JohnDavies, MervPettigrew, Sara

Abstract The giant Schiehallion Field, West of Shetland,

UK, is now entering its midlife period after nearly 10years of production. Understanding the reservoir heter-ogeneity and complex flood front behaviour is nowcritical to future field management. The big seismi-cally-defined pools have been accessed and the nextphases of development will require ever more detailedand integrated geological, petrophysical and reservoirengineering work. Even though geophysical 4D sur-veys and production data have been routinely acquiredin wells from field startup, several key pieces of reser-voir behaviour have been difficult to capture in models.The initial production and injection data showed thatreservoir compartmentalisation had been seriouslyunder-estimated and recent development wells contin-ued to yield surprises. A new approach was needed andby 2007 this was in active planning andimplementation.

Experience West of Shetland shows that the seis-mic can be pushed hard for defining geologicalenvelopes, connectivity and seismic facies regions toallow hybrid seismic-geological facies modelling(Loyal and Foinaven analogues show this well). A newdetailed approach was completed on Schiehallion bylate 2007. More than 300 seismic-scale geological bod-ies were mapped out and as a first pass were populatedwith sophisticated seismic net pay properties. Detailed

geological studies including well log interpretation,core interpretations, and a revised and outcrop-grounded facies model have combined to generate asolid understanding of the geology of the field andtogether with innovative modelling techniques andworkflows has proved successful in understanding thekey geological uncertainties. Reservoir engineeringefforts are primarily focused at the long term manage-ment of the waterflood and in evaluating the benefits ofadditional wells in the field. A major remaining uncer-tainty is the future water cut development in the field asthis impacts the sizing of future production and subseainfrastructure. Further development options and basemanagement decisions need to be robust to downsidesand no upside opportunities can be missed.

A full suite of deterministic models is being builtto capture all main uncertainties and the static anddynamic issues worked out and analysed. The outcomeis a discrete range of deterministic STOIIP models anda suite of history-matched and prediction runs that alsocapture the true behaviour of the field. The final crunchto getting everything together is to integrate the model-ling and analysis efforts with all available data, and tothis effect in addition to outcrop-based ground-truth-ing, there will be full close-the-loop work done on thesatisfactory simulation models through 3D and 4D syn-thetic seismic to tie everything back together.


Integration of Model-Based Seismic Inversion (DELIVERY) in the Stratigraphic Interpretation of Turbidite Reservoirs from the Stybarrow Field and Scarborough Discovery, Western Australia

O’Halloran, GerardHill, RobinWoodall, MarkGoody, AngusGlinsky, Mike

Abstract Model-based seismic inversion is increasingly

recognized as being capable of providing an excellentquantitative reservoir framework for turbidite reser-voirs. This paper explores how a new methodology forprobabilistic model-based seismic inversions (DELIV-ERY) was used in a practical way throughout thedevelopment stages of the Stybarrow oil field and dur-ing the appraisal of the Scarborough gas discovery,both located in northwestern Australia.

Predictions of net sand were used in the case ofStybarrow to plan injector and producer wells, and toenhance post-drill stratigraphic interpretations thathave subsequently been incorporated into detailed res-ervoir models. In the case of the more extensiveScarborough gas discovery, the extent of individual fansystems and their inter-relationships have been inter-preted by incorporating inversion based predictions ofsand thicknesses.

Seismic traverse along Stybarrow oil field,with accompanying Delivery-model-based inversion output for net-to-gross.

OW

C

Top Macedon

Stybarrow-2

Stybarrow-1

Stybarrow-4

OWC

n/g

100%

0%


Sediment Gravity Flow Deposits and Bed-Scale Heterogeneity—Lessons from North Sea Fields

Haughton, Peter D.W.McCaffrey, William D.Davis, C.Barker, Simon P.

Abstract Conventional models for low and high-density

turbidites provide a useful template against which ver-tical and lateral facies trends at bed scale can beassessed. However, such models are only appropriatefor uniform, waning flows that become more dilute asthey run out distally. Significant departures in both ver-tical and lateral texture and structure occur where flowsshow non-uniformity effects or undergo bulking, flowtransformation and partitioning. The North Sea Basincontains a wide range of extensively cored and wellcharacterised deep water systems of Jurassic, Creta-ceous and Cenozoic age.

An important learning has been that conventionalbed models do not apply to parts or all of many of thesesystems. Detailed study of bed-scale facies variationsin slabbed cores have been critical in demonstratingalternative vertical facies trends – the complex struc-

ture of the finer grained lithologies is often difficult tosee in all but wave-washed outcrops. The key buildingblock in many reservoirs is a hybrid bed that captureslongitudinal structure in the original flow involvingtransformation from frictional to increasingly cohesivebehaviour.

The result is that clean reservoir sand is inti-mately interleaved with clay-prone sands at bed scale,particularly in distal and lateral sites where this canhave a demonstrable impact on production. A variety oftypes of hybrid bed are apparent, and their variableexpression is attributed to position, the scale of the sys-tem, the location of erosion, and the level of syn- topost-depositional soft-sediment deformation. As drill-ing extends into the deeper parts of other basins (e.g.offshore mid-Norway and the Gulf of Mexico) similarhybrid are being encountered.


Geological Challenges in Reservoir Modeling, Tahiti Field, Green Canyon 596 / 640, Gulf of Mexico

Mattis, Allen F.

Abstract During the development of Tahiti Field a number

of geological situations were encountered that requiredchallenging and unique approaches to the Total E&Preservoir modeling. Steeply dipping pay sands, poorseismic resolution at the major pay sand level, and the

presence of mud slumps that scoured away the updipedges of some of the pay sands near the rising salt-cored high to the west all complicated efforts to con-struct the Total E&P geological reservoir model.


Waterflood Performance and Time-Lapse Reservoir Characterization of Sand-Prone Mass Transport Deposits: Enfield Field, Canarvon Basin, Western Australia*

Mee, BenMeckel, Lawrence D.

Abstract

The Macedon reservoir sands of the Enfield field,Carnarvon basin, Australia are interpreted as outermostshelf to upper slope deposits. The lower Macedonsands represent the transgressive, shallow marine fill ofvalleys incised during lowstand, while the upper Mace-don sands represent remobilized sediments (sandymass-transport deposits) associated with the collapse ofhighstand shoreface and shallow marine systems into adeeper water setting.

Although the sands have excellent reservoirproperties, stratigraphic and structural complexity andthe characteristics of the fluid column (low structuraldip, heavy oil with unusually low viscosity, gas cap,and limited aquifer) required a development plan that(i) minimized potential compartmentalization issues,(ii) maximized sandface exposure in developmentwells, (iii) prevented gas cap breakthrough, and (iv)allowed for rapid identification, monitoring, and cor-rection of unexpected outcomes. The plan, whichcalled for updip and downdip water injection and hori-zontal producers to minimize the risk ofcompartmentalization, also included the ability to mon-itor well and facility operating conditions in real time,an early monitor 4D survey, chemical tracers to moni-tor waterfront development, and history matching ofdynamic reservoir models.

The start up and early reservoir performance ofthe Enfield development has been broadly consistentwith that plan, allowing for a reduction in STOIIPwhich became apparent after the initial developmentdrilling program was completed. All production wellsachieved their initial design target rates, although side-tracks to the three horizontal wells were required tomanage sand production. The water injection wellshave all performed as expected and the four updipwater injectors in particular have proved effective atpreventing gas cap coning. Evidence to date from wellperformance data and reservoir surveillance data sug-gests that the waterflood is proceeding largely asexpected. However, while many of the original reser-voir development and management strategies havebeen vindicated, there have been also important practi-cal learnings and insights.

Key learnings are that with a relatively smallnumber of high rate production wells in a deepwater,frontier environment, effective sand control and com-pletion reliability is crucial. Initial well and facilitydesign should facilitate subsequent intervention andcontingency plans supported by physical resourcesshould be in place. Integration of key information inthe early life of the Enfield water-flood developmentproject led to improved understanding of the reservoir’sarchitecture and dynamic behavior.

References

Ali, A., I. Taggart, B. Mee, M. Smith, A. Gerhardt, and L. Bourdon,

2008, Integrating 4D seismic data with production related

effects at Enfield, North West Shelf, Australia: SPE Contri-

bution 116916.

Hamp, R., B. Mee, T. Duggan, and I. Bada, 2008, Early Reservoir

Management Insights from the Enfield Oil Development,

Offshore Western Australia: SPE Contribution 116915.

Meckel, L.D., in review, Reservoir-prone mass-transport deposits:

AAPG Special Publication.

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* Oral presentation was withdrawn.


Answering the Challenges of Production from DW Reservoirs: Analogues and Case Histories to Aid a New Generation A-1

Author Index

AAbonaem, Khaled, 13Apps, Gill, 8Archer, Stuart, 4

BBallin, Paulo R., 2Baptista, Noelia, 6Barker, Simon P., 4, 17Bernhardt, Anne, 12Borer, James M., 6Bump, Alex, 2Butler, Robert W.H., 4

CCarr, Mary M., 6Clarke, Julian D., 10, 11Colleran, John, 4Cossey, Stephen P.J., 9Croft, Marion, 14

DDavey, Simon, 15Davies, Merv, 15Davis, C., 17Del Pino Sanchez, Adriana, 4

EEggenhuisen, Joris, 4Elliott, Alison, 14Elliott, Trevor, 10Elsherbiny, Ahmed S., 13

FFarrelly, John, 1Fathy, Alaa, 13Fletcher, John, 15Folefac, Alex, 13

GGardiner, Andrew, 10Gardner, Michael H., 6, 8Glinsky, Mike, 8, 16Goody, Angus, 16

HHailwood, Ernie, 4Hakes, Bill, 4Haughton, Peter D.W., 4, 17Hayes, Ian, 8Hill, Robin, 14, 16

JJobe, Zane R., 12

KKling, Erik K., 6

LLederer, Mark, 2Leishman, Markus, 8Lerch, Chris, 8Locke, Mark, 14Lowe, Donald, 12

MMacdonald, Chris, 15MacGregor, Alan, 15Martin, Karen, 15Mattis, Allen F., 18McCaffrey, William D., 4, 17McCaslin, Neil F., 2Meckel, Lawrence D., 19Mee, Ben, 19Melick, Jesse J., 6Mohammed, Rehab E., 13Moore, Ian, 4

NNapalowski, Ralf, 14

OO’Halloran, Gerard, 14, 16

PPettigrew, Sara, 15Pringle, Jamie K., 3, 10, 11

A-2 Program and Abstracts

RRomans, Brian W., 6

SStanbrook, David A., 3, 5, 10, 11Stoughton, Dean, 8Studlick, Joseph R.J., 9

TTaylor, Katy, 13Thompson, T., 8

WWagerle, Roger, 2, 6White, Chris, 8Wiseman, Terry R., 2Woodall, Mark, 16

Documents

Answering the Challenges of Production from Deep … the Challenges of Production from Deep-Water Reservoirs: Analogues and Case Histories to Aid a New Generation Bob F. Perkins Research