201362 CSPG Reservoir Mag July August

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Rock PropertiesIn This Issue...

Micro-CT Imaging - A Powerful Tool For Screeningand Rapid Quantification of Rock Properties

Montney Core Permeability: A Practical Workflow toAvoid Common Pitfalls

Talking with Architects – Lou Monahan

Determining Physical Properties of Porous MediaUsing Digital Core Physics/Analysis

Trican Geological Solutions, an IntegratedLaboratory with an Innovative Science Approach

201362_CSPG_Reservoir_Mag_July_August.indd 1 2017-06-12 3:56 PM

NEW ISSUE OF THE BULLETIN

Check out the newestissue of the CSPG

Bulletin of CanadianPetroleum Geology

online today atwww.cspg.org

Recognition of wave-influenced deltaic andbay-margin sedimentation, Bluesky

Formation, AlbertaS.E. Botterill, S.G. Campbell, E.R. Timmer and M.K. Gingras

Sedimentology, ichnology and sequencestratigraphy of the Upper Devonian–Lower

Mississippian Bakken Formation ineastern Saskatchewan

L. Zhang and L.A. Buatois

Evolution of Li-enriched oilfield brines inDevonian carbonates of the south-central

Alberta Basin, CanadaG.F. Huff

Regional T-R sequence stratigraphy andlithostratigraphy of the Bearpaw Formation

(Upper Campanian), west-central andsouthwestern Alberta plains

B. Hathway

Maximum age of the basal CretaceousChinkeh Formation sandstones, Maxhamish

Lake area, Liard Basin, British ColumbiaM. McMechan, W. Matthews, F. Ferri and B. Guest

Issue Contents:


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RESERVOIR ISSUE 4 • JULY/AUGUST 2017 3

PRESIDENTMark Cooper

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Shell Canada [email protected]

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NAL Resources [email protected]

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Statoil Canada [email protected]

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Osum Oil Sands [email protected]

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FRONT COVER

Fossiliferous limestone from the OrdovicianGeorgian Bay Formation, Manitoulin Island,Ontario. The fossil fragments, as seen here ina cross-polars thin section view approx. 2 cmacross, are crinoids, echinoderms, bryozoaand ostracods recrystallized to calcite andthen partially replaced by an equigranular,ankeritic dolomite. Fine-grained dolomitethat makes up much of the matrix isintercalated with very fine, dark brown clays.

Jim Renaud

JULY/AUGUST 2017 – VOLUME 44, ISSUE 4

MONTHLY SPONSORS...........................................................................................4

MESSAGE FROM THE EDITORS ........................................................................7

TALKING WITH ARCHITECTS ............................................................................8

ROCK PROPERTIES AND TESTING THEME ARTICLES

Micro-CT Imaging - A Powerful Tool for Screening and Rapid QUantification of Rock Properties............................................................................10

Montney Core Permeability: A Practical Workflow toAvoid Common Pitfalls...........................................................................................12

Determining Physical Properties of Porous Media UsingDigital Core Physics/Analysis ................................................................................14

Trican Geological Solutions, an Integrated Laboratory with anInnovative Science Approach ................................................................................18

UPCOMING EVENTS

Technical Luncheon ...............................................................................................27

SOCIETY NEWS

2017 Student Industry Field Trip ...........................................................................24

GeoConvention 2017: Field trip FT2 “Progress and Challenges forCCUS in Alberta and Canada”. ...............................................................................25

Cspg President’s Award 2016, Brad Hayes .................................................................. 28

H.M. Hunter Award.................................................................................................30

Tracks Citation ........................................................................................................32

MEMBERSHIP UPDATES

Obituaries ................................................................................................................34

FROM THE ARCHIVES .........................................................................................35


29th Annual CSPG/CSEG/CAPL10km/5km Road Race and Fun Run

Wednesday, September 20, 2017

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To register please go to www.cspg.orgMember Rate: $40+gst | Non-member rate: $50+gst | Student & In-Transition rate: $25+gst

Join us on race day on an out-and-back course along the beautiful Bow River pathway. If you arelooking for a competitive race or just want to have fun, come join us!



ROCK PROPERTIES ANDTESTING ISSUE

The editors hope that all our readers areenjoying the bimonthly format of theReservoir and the themes that have

run so far. It is mandate of the Reservoir tokeep content level high, and relevant - thisedition is no exception! Various industrylabs have been invited to showcase some oftheir analytical talents and specialties withapplication to understanding reservoirsand fluids critical to our industry. While itmay be true that working drill rig numbersare on the decline, there is still a lot of highcaliber science and analytics happening.On recent visits to the AER core storagefacility, I’ve been amazed how difficult ithas been to get a table reserved – not tomention it’s nearly impossible to get a tableon a Friday!

Our “Talking with Architects” interviewthis month is with Lou Monahan fromCore Laboratories. Lou is well known andrespected in our industry. His career spansover 30 years with Core Laboratories, andhis knowledge base on routine and non-routine core analysis is remarkable. It wasan absolute pleasure to interview Lou, toget to know his perspective not just throughthe ups and downs of the industry, but alsoon the shifting focus of our industry.

In this edition, we have assembledtechnical papers that deal with non-routinepermeability measurements, digital coreanalysis, micro computed tomography,and a spotlight on integrated laboratoryservices. In this day in age where we arecontinually under pressure to drill the bestwells for the lowest cost, we wanted to shedsome light onto these new and emergingtechnologies. Understanding reservoirsare becoming more and more challengingas exploitation trends towards tightermedia. Laboratory methods are having tokeep pace with these increasing challenges.We hope you’ll find value in learning aboutthese techniques, and perhaps apply it toexisting reservoirs or utilize these methodsto find the next “Big Play”.

As mentioned last edition, we arecontinually on the hunt for timely andapplicable papers. Please don’t hesitate toreach out and contact us for your ideas on apaper or a theme that you would like to seepublished. We realize that everyone’s timeis valuable, and such we want to keep theReservoir applicable, enjoyable and in yourhands. Have a great summer!

Jason FrankTechnical Editor for the CSPG ReservoirSr. Geologist atAthabasca Oil Corporation

Jason Frank is a Professional Geologist who holdsa B.Sc. and M.Sc. from the University of Alberta. He has over 16 years of experience in oil andgas including technical and leadership positionsin exploration and development both on andoffshore. Past experience includes Shell CanadaLtd., Burlington Resources Ltd., ConocoPhillipsCanada Ltd., and Talisman Energy Inc. Jasonhas volunteered for the Society in the past, mostrecently chairing the Duvernay session at theSociety’s annual convention (2014) and theHonourary Address Committee.

Travis HobbsTechnical Editor for the ReservoirProfessional Geologist at Encana

Travis Hobbs is an undergraduate from Universityof Calgary with a graduates degree from SimonFraser University in Geology. Professionally hasworked both domestically and internationallyfor 19 years in the Oil & Gas industry, and iscurrently celebrating 15 years with Encana. Industry roles have included development,exploration, management and businessdevelopment. Prior to the Reservoir,Travis hasheld previous roles on convention committeesand six years as the Chair of ContinuingEducation. As free time permits Travis enjoyscycling, cross-country skiing and teaching his twodaughters violin.

MESSAGE FROM THE EDITORS


8 RESERVOIR ISSUE 4 • JULY/AUGUST 2017

TALKING WITH ARCHITECTSInterview with Lou MonahanBy Jason Frank

Lou Monahan is the Senior TechnicalSpecialist for Core Laboratories RockProperties Group. Lou graduated from St.Francis Xavier University in 1979 with aBachelor of Science Degree. Lou has over30 years’ experience working in the RockProperties department at Core Laboratoriesand has held positions all over Canada.Lou understands more than just thetheory of core analysis; he has significantexperience working hands-on in all aspectsof conventional core analysis. In the late1990’s Lou was responsible for setting upand operating core analysis labs on Canada’sEast Coast to serve our offshore oil and gasindustry.

Presently, Lou is involved in the analysisof shales and other low permeability“unconventional” rocks including offeringtechnical guidance to Operators requiringunconventional analysis and helping toexplain the results.

Questions more on a technicalbackground:1) Working for 30 years at one company,

is almost unheard of in this industry –congratulations! I’m assuming that itwas a job prospect that brought you toCalgary – describe the move ‘out west’and some of the impressions that youfirst had coming to Calgary.

After graduating from St. FX, my buddyand I drove to Calgary in my VW Bug. Sincework was scarce in the Maritimes, we cameto Calgary where the streets were pavedwith gold, to find fame and fortune…or atleast get a job. I had previously not beenwest of Edmundston NB, and driving acrossCanada for the first time was an eye opener.As is typical of many Maritimers coming toAlberta, we stayed on friends and relativescouches until we found work.

2) Just curious, as to what you feel areof the most noticeable changes in theindustry over this time period? It wouldbe neat to hear your thoughts on seeing

a play like the Montney go from a zonethat was just drilled through to one ofthe hottest plays in North America.

The most notable change I’ve noticed is thesteady progression into tighter rocks. The firstMontney I saw was a CanHunter well fromthe Ring/Border field and the rock was quitepermeable and porous. Then a Montneycore arrived that was very fine grained and,for the time, had very low permeability. Iquestioned the play geologist working thearea asking if they had missed core point,implying that this wasn’t the Montney I wasused to seeing. With Operators exploringin tighter and tighter reservoirs, servicecompanies, like Core Laboratories, have hadto design new equipment to analyze suchrock.

3) Being at the very front end of rockanalysis is very exciting – the first tolook at the core, first to get analysis backfrom the core. In your opinion, what arethe most important aspects in analyzinga rock? Has this changed over time?

Yes, Core Analysts are sometimes the firstto see the rock, especially when the coreis taken in a sleeve. We get to be the firstto enjoy the aroma of crude oil, the first totouch the rock and see it under Ultra Violetlight. We usually have a pretty good idea ofreservoir quality before the play geologisteven views it.

I think the most important aspect of CoreAnalysis is for the data user to understandhow the data is generated and thus how touse it or not to use it. The classic example isResidual Fluid saturations from core. Thosevalues are only reservoir quality in specialcases but when a data user sees thosenumbers, they are considered “Gospel”.Although Core Lab offers short courseson most aspects of Core Analysis, I thinkmany data users still do not know where thenumbers come from.

4) When you think about your history

working with Geologists, and theirplays – is there one particular memorythat stands out in your mind? Be it fora technical “Eureka” moment, or thecharacters involved?

In the early 90’s, Core Labs was contractedby Canadian Hunter to go to their Brasseyfield in BC to pick up a core from the Artexformation and I was chosen to perform thejob. This was the first core taken in the Artexformation after the previous rig experienceda blowout and burned down. When thecore arrived at surface, CanHunter wellsiteGeologists from several nearby CanHunterrigs were on the rig floor to see the rock thatcaused the problems. Artex turned out to bethe most prolific oil play in BC. I thought itwas a very cool experience to be involved insuch a record breaking play.

Questions focused on careerdevelopment:1) Having worked from coast to coast here

in Canada, what skill set do you feel ismost important and transferrable?

I think communication is the key whenindividuals from various disciplines arebrought together to solve problems. I’vemet and gone to school with many very

TALKING WITH ARCHITECTS


intelligent people who really know theirstuff but struggle to get their point across.I’m sure we’ve all read technical paperswhere the simple omission of a comma orthe accidental addition of a word (like not)completely changes the meaning. Scientistshave seemed to disregard grammar andspelling and punctuation. If you are tryingto make a point, these things become quiteimportant.

2) Throughout your career lab analyticshas changed a lot – how have you beenable to stay on top of current trends?Are there some analytical techniquesthat you wish were run more often butaren’t?

I’ve been lucky enough to work for acompany that is a leader in the industry.Core Labs designs and manufactures itsown equipment in response to changingrequirements in the industry. TechnicalConventions (like our GeoConvention) areindispensable in sharing new technicalideas with Geoscientists from variouscountries and backgrounds. If there wasone analytical technique I would alwaysrecommend it would be X-Ray Diffractionto investigate mineralogy. Mineralogy playsa very important part in determining howto develop a play and can be very insightful

for a wide variety of issues, like formationdamage.

3) Are there any “pearls of wisdom” thatyou’d like to share to individuals juststarting their careers in oil and gas?

I would encourage young geoscientistsstarting out to not rule out servicecompanies. A young geologist could havean opportunity to see many cores frommany different rock types and reservoirquality from all over the world. Althoughmy own experience of working for the samecompany might not be typical, I estimatethat I’ve probably looked at 10,000 or morecores totalling about 18,000 metres. Aservice company could offer the opportunityfor a geologist to get their feet wet inspectingmany different rocks as opposed to workingat an oil company where a geologist mightbe working one or two formations for years.

Questions centered on more general/ personal items:1) What are your interests outside of the

lab? What do you like to do in yourspare time?

My wife Barb and I enjoy curling in thewinter and Disc Golf in the summer. Ourgranddaughter also keeps us busy.

2) Certainly a 30 year career is somethingto be very proud of – Are there certainthings that you would like to do in thenext couple of years? Both work relatedor outside of work?

My wife and I have attended ballgames at 16different MLB parks. We hope to take at leastone more baseball road trip where we wouldattend a ballgame at each of the 30 MLBparks. I just need to convince my wife.


TALKING WITH ARCHITECTS


TECHNICAL ARTICLE


MICRO-CT IMAGING - A POWERFULTOOL FOR SCREENING AND RAPIDQUANTIFICATION OF ROCK PROPERTIESBy AJ Kumar, Zheng Gan, Lucien Morales,Ted Griffin, and John Dacy, Core Laboratories, 6316 Windfern, Houston,TX, 77040, USA

The micro-CT is a powerful petrophysicaltool which uses high intensity X-rays tocreate closely-spaced high-resolutionimages. In core petrophysics micro-CTimaging is used for multiple purposes, fromscreening plug samples for specializedtesting to assessment of reservoir quality bymodeling certain rock properties.

Depending on the objectives, images can beacquired at various resolutions, ranging from20 to 0.3 microns. Resolution is a functionof source-detector spacing, scan time, andproximity of the sample to X-ray source.In general, the highest resolution imagingnecessitates smaller sample size. For example,a typical core analysis plug sample can bescanned at a 20 micron resolution whereasmicro-plugs, which are 5mm in diameter, canbe scanned at a 0.5 micron resolution. Figures1 and 2 provide illustrations of sample sizesand corresponding images acquired using amicro-CT.

On plug samples, excellent visualizationof geologic features and drilling inducedanomalies are achieved with a 20 micronresolution scan. High resolution imagingdata, when viewed interactively on slice-by-slice basis, assists in the sample selectionprocess and screening for sophisticated,reservoir-condition flow studies and geo-mechanical testing. This high-resolution,three-dimensional imaging of core plugshelps geoscientists better understandvariations in the pore system properties thatmay impact both laboratory analysis andreservoir performance. Figure 3 highlightsthe heterogeneity in a plug sample andwhy it should not be chosen for a core floodtest. At this resolution, quantification of vugporosity, fracture porosity, fracture aperture,etc. can also be performed.

Micro-CT scans at higher pore scaleresolutions help resolve features as smallas 0.3 micron. Image acquisition and

segmentation at such resolutions aid ingrain and pore system characterization.This operator independent characterizationresults in a host of image-derived data with

help of industry standard segmentationsoftware. When consolidated withappropriate physical measurement-based models, petrophysical data such

Figure 1: 1-inch diameter plug sample scanned at 20 micron resolution

Figure 2: A 4mm diameter plug sample scanned at 1.5 micron resolution


TECHNICAL ARTICLE


as permeability, capillary pressure, andelectrical properties can be quantified. Sincethese models are constrained by physicalmeasurements, the modeling confidencelevel is improved. Figures 4, 5, 6, and 7illustrate comparisons between physicalmeasurements and micro-CT modeledproperties. These scans and propertyquantifications are also ideal for friable tounconsolidated samples, large sized drillcuttings, or in cases when core recovery ispoor. The rock-based, digital, physically-constrained models provide data whichrelate well to conventional core analyses.

Acquisition and segmentation of a single set

of images are needed for sample analysis.Overall turn-around-time is reduced forquantification of properties, given theefficiency of these rock-based physically-constrained models on moderatelypowerful computers. Rapid access to keypetrophysical properties helps operatorsmake time-dependent critical decisions.

This presentation will demonstrate whatmicro-CTs are capable of, from a core pluglevel scanning and screening to ultra-highresolution scans of small samples, leadingto quantification of routine and specialproperties.

Figure 3: 20 micron resolution scan of a plug; highheterogeneity in this plug makes it unsuitable forcore flood tests

Figure 4: Comparison of permeability data: physical measurement vs micro-CT physically-constrained models

Figure 5: Comparison of capillary pressure drainage curves: physicalmeasurement vs micro-CT physically-constrained models for a highpermeability rock sample

Figure 6: Comparison of capillary pressure drainage curves: physicalmeasurement vs micro-CT physically-constrained models for a lowpermeability rock sample

Figure 7: Comparison of cementation exponent, m: physical measurement vsmicro-CT physically-constrained models


TECHNICAL ARTICLE


MONTNEY CORE PERMEABILITY: A PRACTICALWORKFLOW TO AVOID COMMON PITFALLSBy Joe Ramoin, John Dacy,Author Affiliation: Core Laboratories Canada Ltd.

Discussion and debate continues regardingbest methods and workflows for measuringpermeability and other routine coreanalysis parameters in tight unconventionalreservoirs. In this article, we describe arecommended, quick evaluation workflowfor measuring unfractured, slip-corrected(Klinkenberg) permeability in the MontneyFormation, without synthetic alteration ofthe rock matrix.

A primary objective for almost every coreanalysis program is to gain a thoroughunderstanding of permeability and porosityrelationships and rock type variability tobuild an accurate core-to-log calibrationmodel for asset development, reservoirsimulation, and economic expectation.Fundamental to these building blocks isattaining high-quality routine permeabilitymeasurements that are not skewed byanomalies (fractures) or laboratory variables(slippage). Core Laboratories has worked onhundreds of Montney cores and receivedfeedback from our clients on best methodsand workflows to achieve desired results inthe Montney Formation. A brief summary isdiscussed below, but first some backgroundon a major inherent laboratory permeabilityartifact in tight rocks and how to account for

it.

Many factors affect routine laboratorypermeability measurements. Propercleaning, drying, sample preparation, andnet stress effects are some well-knownvariables that must be accounted for andcontrolled as a potential source of error.Another less recognized variable and sourceof error that can have a dramatic impacton routine permeability measurements isslippage. Slippage has a dramatic impacton permeability in micro to nanodarcyrock, such as the Montney, and needs tobe understood and accounted for in properreservoir characterization. For reference,permeability to air (with slippage) inthe microdarcy to 100 nd range may beoptimistic by 1 to 2 orders of magnitudecompared to slip-free values.

Slippage is a phenomenon related to themean free path of gas molecules. As themean free path varies with temperature,pressure, and gas composition, slippage andapparent permeability will vary. The effectof slippage ranges from insignificant in highpermeability media to of great consequencein low permeability media, e.g., Montney.Gas at reservoir pressure is nearly equivalent

to a non-reactive liquid (low mean free path)and apparent permeability is essentiallyslip-free (Klinkenberg or Kinf ). Oil and gaswells flow liquids or gas at high pressure,neither of which are affected by slippage.For efficiency and convenience, coreabsolute permeability is often determinedusing gas at low pressure and slippage canmake computed permeability optimisticcompared to observations from formationsthat are controlled by the absolute, slip-freepermeability. Core perms-to-gas (e.g., air)are due corrections for slippage (amongother corrections) to be representative ofreservoir absolute permeability. The degreeof correction varies with rock type, levelof absolute perm, and test conditions (gastype, mean flowing pressure). A ‘slip-free’absolute permeability is the intrinsic value,equivalent to flow of non-reactive liquidand affected by neither gas composition normean flowing pressure.

Accounting for slippage and provisionof Klinkenberg permeability in core datais usually accomplished by one of twomethods. The ideal method is to directlydetermine enough flow data on a specificsample to “measure” both the Klinkenbergpermeability and the slip factor, b, for that

Figure 1. Visual fracture inspection after plugcleaning and drying.

Figure 2. Example of helical CT on plug thatpassed visual examination. This figure showspresence of internal fractures on multiple axes inour 3D browser.

Figure 3. Example of helical CT on plug thatpassed visual examination. This figure showspresence of internal fractures on multiple axes inour 3D browser.


TECHNICAL ARTICLE


sample. This is accomplished either bymultiple steady-state flow tests at varyingmean flowing pressures or by a singleunsteady-state pressure falloff test. A lessideal alternate approach is to measurea single steady-state air permeability ata mean flowing pressure and use a slip-factor correlation to compute the slip-freepermeability. Using the variation seen inslip-factor correlation data, for example, acorrelation-derived kinf of 150 nd may beas high as 320 nd or as low as 80 nd. Thisvariation will be greater when one considersthe variety of a more global data set. Slippageis accounted for in a sample-specificmanner in the work-flow described belowby use of devices that employ the unsteady-state pressure falloff method (CMS-300™ andPDPK-400™).

In addition to accounting for slippage,avoidance of induced fractures inpermeability assessments is also paramountto a proper reservoir characterization study.Once plug samples have been cleaned anddried, each plug is visually inspected forfractures or microfractures (Figure 1). Anysamples that do not pass the visual inspectionare removed from the primary workflow.Plug samples that pass visual inspectionare CT scanned by high-frequency helicalCT (Figures 2 and 3) or micro-CT (Figure 4)down to 20 micron resolution for evaluationof internal or surface fractures not seenduring visual inspection. Samples withfractures observed by high-frequency 3D

CT are removed from the workflow andthe rest undergo Klinkenberg permeabilitymeasurements in the CMS-300™ at minimal,reservoir-condition, and several depletioncondition net stresses up to 52,000 kPa.Permeability-porosity cross plots areexamined. For samples that deviate from thegeneral trend, visual inspection steps aboveare repeated, as some fractures may havebeen missed or subsequently developedduring permeability measurements atstress conditions. To improve assuranceof fracture avoidance, post-test CT ormicro-CT imaging has been preferred bysome operators. Samples that do not passoriginal or subsequent visual inspectionand CT screening may undergo Klinkenbergprobe measurements by Pressure DecayProfile Permeameter (PDPK-400™) onunfractured sections (Figure 5). These probepermeabilities can be stress-corrected basedon the stress response seen in plugs.

In summary, if proper screening steps andpermeability techniques are utilized, theresult is a high-quality routine core analysisdata set that that can be used with confidencefor core-log calibration, evaluation, andinput to reservoir simulation (Figure 6).

This paper has shown what micro-CTs arecapable of, from a core plug level scanningand screening to ultra-high resolution scansof small samples, leading to quantification ofroutine and special properties.

Figure 4. Plug mirco-CT inspection at 20 micronresolution identifying micro-fractures not seen byother methods.

Figure 5. PDPK-400™ measuring slip-correctedpermeability on cleaned slabs.

Figure 6. Example k-phi data set employingexamination methods set out in this article.


TECHNICAL ARTICLE


DETERMINING PHYSICAL PROPERTIES OF POROUSMEDIA USING DIGITAL CORE PHYSICS/ANALYSISShahin Ghomeshi1, Jonathan L. Bryan1,2, Peyman Mohammadmoradi1, Farzad Bashtani1, Saeed Taheri1,

Meysam Rahmanian Shahri1 and Apostolos Kantzas1,2

1: Department of Chemical and Petroleum Engineering, University of Calgary2: PERM Inc. Calgary

IntroductionThe ability to measure or characterizethe properties of porous media is key tothe successful recovery of hydrocarbons.Reservoir petrophysics and log/coreanalysis have long been the major methodsused for interpreting and modeling thesereservoir properties. Such characterizationis especially important in unconventionaloil systems, but it is in these systems inparticular that many of the “routine”measurement procedures developedcannot be used easily or reliably. It is wellknown that the pore size is a fundamentalscale in understanding the displacementprocesses and estimating global transportproperties of porous media. In recentyears pore level imaging and modelinghas advanced into a predictive tool forthe oil and gas industry, and carries withit several names such as digital coreanalysis (DCA), digital rock physics (DRP),or computational rock physics (CRP).Although it is scientifically challengingtask, DCA has the potential to predictthe behavior of porous media by directlyobserving its structural properties withoutthe need for expensive experiments. Theworkflow involved in DCA is composed ofthe primary steps: (a) digital imaging fromhigh resolution 2D and 3D scans that canresolve the pore level features of the rocks,(b) performing image analysis in order toprocess the raw images where pores andthe different minerals are identified andsegmented based on their gray scale, (c)using numerical simulation algorithmsto solve the governing equations of flowwithin the porous structure (micro or sub-micron) in order to predict its physicalproperties. The level of sophisticationin these steps determines the predictivepower of DCA. This paper addresses theadvances made within our group over thepast few years. Some illustrative examplesare included.

Some physical properties of porous mediathat are of primary interest including boththe single and multiphase flow properties,are the total and effective porosities,absolute and relative permeabilities,electrical resistivity, formation factor, andthermal conductivity. It is important thatthe numerical algorithms used, correctlyapproximate these outputs of interestwithin the porous media domain so thatthey can be used as a predictive tool forenhanced oil recovery (EOR). However,with the exception of total porosity, thesephysical properties become relevant onlyin the presence of a continuous field ofhydraulics going through the pore structureconnecting the inlet to the outlet, such asfor example the hydraulic permeability.Any quantitative information must be atthe resolution corresponding to the sizeof the structural units (i.e. the pores andthroats) in order for the image processingsoftware to threshold the different grayscales of the image, identifying theconnections between the pores andthroats. Therefore, properly capturingthe pore structure and its interconnectedstructural units through high resolutionimaging and image processing are vitalprior to any computational modeling.

Pore-throats form a continuum in siliclasticrocks and range from submillimeter tothe nanometer scale1. There has beensignificant progress in 3D tomographicimaging techniques to directly imagethe structure of rocks across a variety ofdifferent length scales2. In conventionalreservoir rocks, the diameters in the pore-throat sizes are typically greater than 2μmand so micro-CT scans can produce goodimages from rock samples. However,hydrocarbon extraction from poor qualityrocks is becoming more common and soin tight sandstones the sizes range from2 to 0.03 μm, and from 0.1 to 0.005 μm in

shales1. For these sub-micron sizes, theimaging technique required combines afocused ion beam (FIB) with a scanningelectron microscope (SEM) to obtaininformation about their internal structureat this much higher resolution.

Imaging and Image ReconstructionThe main limitation in the imaging stageis that high resolution images of the rockare not always available or we have only aninadequate number of 2D cross-sectionalimage samples of the rock. If 3D imagesare available (e.g. from micro-CT), thenaccurate representations of the mediumunder investigation can easily be created2.With limited 2D images it is challengingto construct a 3D representation of therock that properly captures the physicalconnectivity and arrangement of poresin space. In this case, other methods maybe used to construct three-dimensionalrepresentations of the pore space fordifferent types of rocks. These are thephysics based modeling3, and the statisticalreconstruction approach4,5,6. In physicsbased modeling, one can use the largeavailable inventory of particle (grain)size distribution (PSD) data in order tomathematically construct porous mediathat will represent packing of regular/irregular grains3. Figure 1 is an exampleof a porous medium generated from aninput PSD. A virtual porous mediumis generated based on cubic packing ofspheres with various size distributionsto mimic unconsolidated and partiallyconsolidated sands. However for loosepacking of spheres typically the porosityand permeability are higher. Therefore,another approach is developed such thatthe shape, orientation and structure ofthe grain can be readily controlled. Thisapproach enables irregular shaped grainpacking that can mimic consolidated sandsand tight formations based on the PSD7.


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In the case when there are only a limitednumber of 2D cross-sectional imagesavailable, statistical reconstruction canbe invoked in order to generate more 2Dcross sections from a single or limited fewsamples thereby preserving connectivityand obtaining a geologically representativepore space5. 3D reconstruction is thenperformed from the generated 2D cross-sections.

Prediction of propertiesWhen a 3D image reconstruction iscreated, the calculation of properties canbe obtained through one of the followingmethods:

Pore Network Modelling: This approachgoes back in the traditional work of Fatt8and through numerous reincarnationsleads to the work presented by Bluntamong others2. The 3D structure istransformed into a network of nodes andbods with predefined geometries. Quasi-static displacements are mimicked andall petrophysical properties are predicted.The method is very fast to use but the poregeometries are unrealistic. If capillarypressure data are available then thepredictions of relative permeability andresistivity index curves are reasonablyaccurate. Otherwise there are multiplesolutions that can be generated fromnetworks that match given porosity andpermeability.

Pore Morphology Approach: Inthis approach9 the actual images aretransformed into a 3D grid and propertiesare directly calculated using single phasetransport equations and multiphase quasi-static displacements. The accuracy isincreased since the actual images are used(within the resolution limits). However,computational intensity is also increased.

Direct Numerical Modeling Approach:Here true multiphase flow equations10,11

are implemented throughout allcomputations. The computationalintensity increases multiple orders ofmagnitude. Also numerical instabilitieshamper conversion thus making thisapproach still a future goal rather than aneveryday tool.

The most widely used direct numericalsimulation techniques for solving thesingle and multiphase flow equations arethe Lattice Boltzmann method, or the FiniteElement and Finite Volume methods. TheLattice Boltzmann method is a particlebased technique used in simulating themotion and collision of particles on a grid;and is supposed to be an approximation tothe molecular model of flow governed bythe Boltzmann equation. In our work wemodel the flow as a continuum governedby the Navier-Stokes equations. At thepore-level, we are often in the presenceof creeping flow regime where inertialforces are much less than viscous forces.In this case for the single phase flowcalculations, the Stokes’ equation becomea good model and is invoked instead. Thiscan reduce the computational complexitydue to the fact that the Stokes equation islinear. For single phase flow calculationswe implement the Finite Element methoddue to the fact that it can readily handlecomplex geometries and also higher orderaccuracy can be obtained.

For two phase flow calculations aninterface advection term is added to the setof governing equations, and we discretizethe flow equation using the Finite Volumediscretization for the Navier-Stokesequations, and the Volume of Fluid (VoF)method for interface capturing. This VoFmethod is chosen particularly because of ithas intrinsic mass conservation properties,whereas other popular implicit interfacecapturing techniques such as the level setmethods are not mass conservative10,11.

It must be noted that contrary to reservoirsimulation where petrophysical propertiesare input, in the aforementionedmethodologies the petrophysicalproperties are output. In the followingsection, some illustrative examples arepresented to demonstrate the capabilitiesof different methods. Details of the

different methodologies can be found inthe cited references.

ExamplesSome Numerical Results for PhysicsBased ModelsFrom spherical packings, we have theadvantage that we can verify the numericalsimulation for permeability for equal sized(homogeneous) porous media using theKozeny-Carmen relation. The simulationresult for a 1500 grain packing is shown inFigure 2 where velocity profile is computedby solving the Navier-Stokes equation andcontinuity equation in the domain withnon-slip boundary conditions and thegrain walls, and the absolute permeabilityis calculated through Darcy’s equation

k= uμL/∆p,

where L is the medium length in thedirection of flow (m), u is the Darcianvelocity (m/s) through the inlet face,μ is the fluid viscosity (cp), and ∆p= is the pressure drop (Pa), and k isthe permeability (D). Comparison ofthe numerical permeability with thatpredicted by the Kozeny-Carmen equationfor different grain diameters is then shownin Figure 3.

(Continued on page 16...)

Figure 1: (a) depicts grains size distributionobtain from oil sands data. (b) depicts regulargrain packing generated from the distributiondata in order to mimic unconsolidated sandpacks (c) depicts packing of irregular grainsbased on the grain size distribution where onlythe sphericity of the grains are changed.3

Figure 2: (a) Generated regular cubical packingof uniform spheres, (b) velocity profile as a resultof sub-pore scale computations.3

Figure 3: Permeability predictions usingKozeny-Carmen equations and sub-pore scalecomputations.3


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A more detailed review of permeabilitycalculations in unconsolidatedhomogeneous sands is given elsewhere4.

Construction of the irregular shapedpacking is inspired by the crystallizationprocess where the size and shape ofthe grains is controlled by altering thesphericity of the packings. In Figure 4 weshow some numerical calculations for theirregular packing of resolution 5 micronsand 200×200×200 grains where for thedifferent sphericities, the porosity thepermeability (k) and the formation factor(FF) are given Figure 4:

For the purposes of understanding thepore-level mechanisms associated withthe displacement process by properlypredicting residual oil trapping, snap off,Haines’ jumps and ganglia mobilization,mass conservation within the numericalalgorithm is crucial. Unfortunately,the slow computation times for thesecalculations, especially for real 3Dproblems is the main delimiting factor. Inorder to mimic the recovery process wenumerical simulate the primary drainage,and once breakthrough is reached, weperform a secondary imbibition process.The computational times for numericallysimulating a primary drainage process in a3D porous media consisting of 1600 grainsand only 2mm in length will take nearly 2months of run time on a 128 processors. InFigure 5 we perform direct two phase flowcomputations using a 200 grain packingwhere in (b) we show primary drainageprocess and in (c) secondary imbibitiontakes place where residual oil entrapmentby snap-off can be observed.

Some Numerical Results for 2DReconstructed ModelsFigure 6(a) depicts a 3D reconstructionprocedure where only three SEM samplesof Nordegg are available. The SEM imagesare 5120 × 3828 pixels (~ 637 × 476 microns)and are highly heterogeneous with largerange of grain sizes. We provide a giventolerance for the different grain sizes intosmall, medium, and large. The imagesare then decomposed into permeable andimpermeable domains. The permeabledomains are at sub-pore scales where weextract several (33 images) statisticallysimilar images that are 256 × 256 pixels(~32 × 32 microns) from the three imagesand perform spline interpolation betweenthe gray scale of each 2D cropped image.After the 3D reconstruction of the smallscale pores as in Figure 6(b), we employpore level numerical simulation to obtainthe permeability and electrical resistivitywithin the small pores in which the resultsare depicted in Table 1. For the two phaseflow properties within the small grainsizes we use the Pore Network Modelingtechnique because it is faster, especially forporous media of such complex topology.The capillary pressure curves based on theNetwork models are depicted below.

In any DCA, once pore-level numericalsimulation results are obtained,procedures to upscale the pore scale dataare invoked yielding volume averagedquantities that have the desired practicalapplications. Here we use an earlyupscaling approach where from the smallsample where permeability is computedthrough the smallest grains, we useand averaging procedure to predict theproperties for the entire SEM sample. Forthe impenetrable parts (i.e. medium andlarge grains), we then map out the largeand medium sized grains from the originalimages as in Figure 6(c) and use an erosion/dilation approach in order to recreate the

up-scaled core plug. We then assumethe permeability obtained from the pore-level simulations within the smallest rocksseen in Figure 6(e), and invoke an averageprocedure to estimate permeability for thecore. The 3D recreated geometry is shownin Figure 6(f ). The details of the averagingprocedure are given elsewhere4.

Some Numerical Results andApproaches for Tight FormationsIn this case, we are given 600 2D FIB-SEMimages of a tight formation. During theimage segmentation (or thresholding)procedure, we can binarize the 2D cross-sections into pore space and grains, andonly discretize the pore spaces using aCartesian grid. This is computationallyless expensive then discretizing the entiredomain, and it is a common approach forsolving the equations of fluid flow suchas the Navier-Stokes’ within the poreswith appropriate boundary conditionsat the pore walls. However sometimes

(Continued from page 15...)

Figure 4: Different single phase flow propertiesfor packings of irregular shaped grains based byvarying their sphericity.7

Figure 5: (a) 200 grain sand pack; (b) oiloccupancy profile at the end of drainage (b)and imbibition (c); (c) shows trapped oil due tosnap-off.

Figure 6: (a) represents the different samplescontaining small grains cropped from the 3SEM images and (b) the 3D reconstruction ofthe images cropped along with those derivedfrom interpolation; (c) shows the mappingout of the large impermeable; (d) representshow the medium grains and large grains aremerged together after they are mapped out;(e) highlights the zone where the permeabilitycalculations are applied and (f) depicts thereconstructed domain4.

Table 1: Tabulated results from the pore-scalesimulations


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it is necessary to discretize the entiregeometry. This is true for example, whencomputing the flow of ions within theporous media. Grains can have almostnegligible electrical conductivity, howeverpore structures consist of many differentminerals. Some of the most common,such as pyrite may be present and theirelectrical conductivity should be takeninto consideration and incorporated intothe model. Figure 7 is an example of atight formation consisting of differentminerals. Proper segmentation of the porespace and minerology can greatly impactthe numerical results. In Figure 8, we takeone quarter of the sample in Figure 7 andthreshold it by considering only the porespace as in Figure 8(b), or retaining thedifferent minerals as in Figure 8(c). Figure8(a) depicts the Pore Network Model ofthe same sample consisting of a simplifiedrepresentation of the pores and throats.

The absolute permeability is computed inthe different directions and the results aregiven in Table 2, and the capillary pressurecurves are derived from employing quasi-static pore morphology approach9.

In order to capture the physics of theflow in the narrow pathways, the voxel(mesh) size must be smaller than the poreand throat sizes. In the case of shale, forexample, just to be able to investigatemethane adsorption in nanoporousKerogen the size of the mesh can cause thecomputational requirements to becomeprohibitively expensive. One way aroundthis is to crop smaller samples and/or useadaptive mesh refinement where neededin order to make the problem amenable tocomputational physics approach. Figure10 represents a cross-section in the y-zplane of the tight rock sample from Figure7. This sample consists of organic Kerogenand in order to simulate flow, we croppeda tiny sample which is representativevolume of the sample and we study itsproperties. The resolution of the tight rockimage is 15 nm/pixel, however higherresolution is required to properly segmentthe pores within the organic material.Therefore, stochastic reconstruction ofthe pore space performed with 5nm.pixelresolution.

ConclusionDifferent approaches for Digital CoreAnalysis within natural porous mediapatterns have been presented and someof the challenges have been highlighted.The use of high resolution images and/orreconstructed images of real porous mediacoupled with numerical algorithms of flowcalculations shows promising technologyas a predictive tool for petrophysicalproperties currently and EOR in the future.

References1: Nelson, P.H., 2009. Pore-throat sizes in sandstones,tight sandstones, and shales. AAPG Bull. 93, 329-340.

2: Blunt MJ, Bijeljic B, Dong H, Gharbi O, Iglauer S,Mostaghomi P, Paluszny A, Pentland C, 2013. Pore-Scale imaging and modelling. Advances in WaterResources, 51, 197-216.

3: Taheri, S., Ghomeshi, S., Kantzas, A., PermeabilityCalculations in Unconsolidated Homogeneous Sands.J. Powder Technology, submitted.

4: Ghomeshi, S., Taheri, S., Skripkin, E., Kryuchkov,S., Kantzas, A., Determining of Physical Propertiesof Tight Porous Media using Digital Core Physics/Analysis, SCA2015-052.

5: Oren, P.E., Bakke, S., 2002. Process basereconstruction of sandstones and prediction oftransport properties. Transp. Porous Media 46 (2-3):311-343.

6: Oren, P.E., Bakke S., 2003. Reconstruction of Bereasandstone and pore-scale modelling of wettabilityeffects. J. Petroleum Sci., and Eng. 39 (3): 177-199.

7: Rahmanian, Shahri, M., Taheri, S.,Mohammadmoradi, P. and Kantzas, A., “StochasticGeneration of Virtual Porous Media Using a Pseudo-Crystallization Approach”, submitted, Energy andFuels, 2017.

8: Fatt I. 1956. The network model of porous media I.Capillary pressure characteristics. Trans AIME 207:144-159

9: Mohammadmoradi, P., Kantzas, A., 2016.Petrophysical characterization of porous mediastarting from micro-tomographic images, Advances inWater Resources, 94:200-216.

10: Santiago, C., Ghomeshi, S., Kryuchkov, S., Kantzas,A., Pore level modeling of imbibition in heavy oilsaturated media. 2016. J. Petroleum Sci., and Eng. 140:108-118.

11: Raeini, A., Blunt, MJ., Bijeljic, B., 2012. ModellingTwo-Phase Flow in Porous Media at the Pore Saleusing Volume-of-Fluid Methode. J. Comp. Phys, 231:

5653-5668.

Figure 7 (a) represents a cross-section of a tightformation having 15 nm resolution consistingof many different minerals. (b) is the 3Dreconstruction obtained from 600 images, oneof which is (a).

Figure 8: (b) represents the pore space, whereasin (c) we have identified the different mineralswhich are thresholded and are incorporated intothe model in solving both electrical and thermalconductivity. (a) is the corresponding PoreNetwork Model simplification.

Table 2: Tabulated results from the tightformation tests

Figure 9: Capillary pressure curves for the tightformation sample in the different directionsusing quasi-static displacement from pore-morphological approach.

Figure 10: (a) is a y-z plane cross section ofthe tight rock image containing Kerogen. (b)is the stochastic reconstruction of pore spaceinside the organic material (Kerogen), and theresolution is (5nm/pixel)


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TRICAN GEOLOGICAL SOLUTIONS, AN INTEGRATEDLABORATORY WITH AN INNOVATIVE SCIENCE APPROACHINTRODUCTIONTrican Geological Solutions (TGS), anAlberta, Canada, corporation, was foundedin 2000 (formerly CBM Solutions Ltd.)to evaluate coalbed methane projectsthroughout Canada and the United States.Advances in technical research withinthe group led to the company’s evolutioninto a multifaceted, full service lab, withapplications in routine and special coreanalyses, caprock analysis, unconventionalfracturing optimization, wellbore stabilityanalysis and geotechnical rock testing. Aspart of Canada’s largest pressure pumpingservices company, Trican Well Service Ltd.,the TGS team delivers evaluation and datainstrumental in enhancing well completionservices, with a focus on unconventionalreservoirs.

With the recent economic downturnin the oil and gas industry, geologicalinvestigations have shifted to generatingmore data from limited sample materialas well as to optimize completion designand well stimulations (including fluid orproduction damages). To facilitate thesechanges, TGS has invested significantlyin developing methodological and testingprocedures as well as increasing computermodel and simulation applications gearedtowards improved understanding ofunconventional reservoirs and optimizingconventional reservoirs. Currently, TGShas capabilities to complete an arrayof laboratory analytical capabilitiesincluding local and regional geological/geotechnical studies, project evaluationsand consultancies for shale, tight-rock,SAGD, coalbed methane reservoirs andconventional reservoirs.

With marginal economics and increasinglychallenging reservoir evaluations,geoscience of core analyses has becomemore rock- and formation-specific.Research and studies over the last 10years have demonstrated that applicationsof conventional techniques to evaluateunconventional or tight oil-gas playsno longer provides the level of detail or

accuracy needed. Thus, more complexand more technical advanced analysesare performed. Analytical programs nowcommonly include a combination ofgeochemistry, rock mechanics, routine andspecial core analysis, gas-in-place and oil-in-place modeling, natural gas liquids yieldmodeling, petrophysical modeling andpetrographic, SEM and CT imaging.

Trican Geological Solutions has assembleda team of experienced professionalsdedicated to carrying out the uniqueservices required to evaluate complexreservoirs around the globe. To date,TGS has completed evaluation projectsand studies throughout Canada, theUnited States, India, Argentina, Peru,Colombia, England, Turkey and Australiafor approximately 200 individual clients.Several hundred evaluations and studies,involving in-house testing of over athousand wells, have been completed inNorth America alone.

To better understand reservoirs in themodern age, TGS has focused on a numberof areas for developing new approaches ofgrowing concern:

• methods to better characterize andunderstand routine rock propertiesincluding porosity, which markedlyinfluences common resource in-placeevaluations

• methods and approaches to utilizecuttings material to either replace orsupplement core and other analyticaldata while minimizing expenses for E&Pcompanies

• analytical programs and methods forimproving caprock integrity testingprocesses

GETTING A BETTER HANDLE ONPOROSITYIn the world of conventional reservoirs,porosity measurements are routine withextremely quick turnaround time on

testing. As unconventional explorationrapidly evolved, testing practices fromconventional reservoirs were adaptedwith little to no consideration for thecomplex nature of pore systems in tightand unconventional reservoirs. In otherwords, the fast-paced nature of the oil andgas industry had little patience for thedevelopment of an appropriate method forunconventional plays, let alone the time towait for long testing schedules. As a result,much data is considered inaccurate butindustry was willing to accept that dataas “close enough”. Detailed research onthis issue in our laboratory over the last 5years has demonstrated that this approachresults in inaccuracies of as much as 20to 25 percent or more in some cases.Resource calculations, recovery factors andproduction schedules are all impacted in acritical and significant way.

If the recent downturn has a silver lining,it may be in that it has allowed companiesto refocus and re-evaluate. With accessto unevaluated data and laboratorycapacities for research and evaluations ofmethods, a disconnect between measuredreservoir volume (porosity) and productionvolumes has been identified. Re-evaluations on archived core consistentlyshowed that porosity and saturations areunderestimated. The fundamental issuethat produced such inaccuracies of thesemethods: time. Conventional testingstandards do not allow the time requiredto clean/extract an unconventional ortight rock sample given the tight natureand tortuous flow paths found in suchplays. Low permeability rocks, less than0.1 mD, are notoriously “under evaluated”and show high concentrations of residualhydrocarbons and retained solvent fromthe extraction process.

Understanding the limitations of currenttesting procedures led to the development ofa modified extraction process which allowsfor more complete measurement of bothsaturations and porosity and have showntighter correlation to log derived porosity


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values. The underlying premise being that asample being tested for porosity with retainedhydrocarbons and solvent will certainly givean underestimation of porosity.

In conventional rocks with 15 percentporosity or more, small amounts of retainedfluids prior to porosity analysis, does notmake a significant difference in the final

data. However, in tight rocks, micro- tonano-scale pore space can markedlyinfluence final porosity values and results ina significant difference or an uplift of 20 to25 percent or more in resource calculations.Time is well spent in understanding theprocesses involved in deriving a porosityvalue and determining a comfort levelin the steps to achieve that value. As a

simple example, the measurement of bulkdensity makes up half of the equation whendetermining porosity:

Ø=1-(Density_bulk)/(Density_skeletal )

Bulk density is routinely measured intwo ways: 1) immersion in mercuryand 2) caliper measurements. A studypresented by the Society of Core Analystsin 2014 looked at the impact of bulk densitymeasurements using chalk samples. Thefindings, which are consistent with thoseof TGS, show that mercury immersion hasa relative volume error of +/- 0.01 cc whilecaliper measurements show a relativevolume error of +/- 0.15 cc. Figure 1-2 showsthe impact on porosity resulting from errorassociated with both mercury immersionand caliper measurement techniques. Invery low porosity systems, the associatederror with measurement technique alonecan be extremely significant.

At Trican Geological Solutions, wehave developed a novel approach todetermining both saturations and porosity.Historically, the methodology has relied ona predetermined timeframe to extract thesamples. The new methodology relies on aniterative approach to extract, evaluate andrepeat the process until a end point can bemeasured.

GOING BACK TO THE CUTTINGSIn a world hyper-focused on cost and overallreturns (benefits), the value of well cuttingsmaterial for providing important data forgeological or well completion decisionsmust be highlighted. For years, operatorshave been saving small vials of cuttingsmaterial, usually as an obligation to satisfygovernment regulations. Literally tonnesof sample material are disposed of everyyear without a second thought as to theirpotential values. Retaining bulk wellsitecuttings is a low-cost piece of insurance toallow for future testing. Granted, cuttingsare not all equal and quality is only asgood as the person collecting them, but ifcollected properly, they hold an incrediblewealth of information. Hence, cuttingsdata can hold an tremendous value forimproving both reservoir completion aswell as production understanding.

In a time when long-reaching horizontal

Figure 1 1: Chromatogram showing the distribution of hydrocarbons of a previously cleaned core plug(red line) and the same sample after a modified extraction process designed for tight rocks (blue line).

Figure 1 2: Error in porosity measurement associated with mercury immersion and caliper techniques fordetermining bulk density.



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wells (1000-3500 m) are the norm, wetypically have a limited view of geologicalchanges happening along the wellbore.Is a 50 m sampling frequency and briefgeological description enough when yourstage spacing is 40 m? Considering thata core was available for log calibrations,with long lateral wells, the toe of the wellcan be >3000 m away from the controlsection. How well does core data correlatenow? Advances in geochemistry, imagingand basic rock property testing allow usto examine the cuttings more closely andextract more information than we ever havein the past.

The emergence of high resolutionhandheld XRF geochemical units thatallow the measurement of elements fromNa to U, is an example of technology beingapplied to economically collect high-resolution data in a single wellbore andto correlate data across multiple verticaland horizontal wellbores in a field. Aswith all instrumentation, understandingthe limitations of such instruments is keyto getting the most out of it. In the caseof XRF geochemistry, formation-specificcalibrations are an absolute must toachieving accurate and meaningful results.While data can be extremely valuable,laboratory comparisons have demonstratedthat poor calibrations or precision have ledto inaccurate data output (i.e. “garbage inequals garbage out”) (Fig. 1-3). Figure 1-3provides an example of a calibrated andan uncalibrated silica (Si) profile from theMontney Formation.

At Trican Geological Solutions, toeffectively use handheld XRF (HHXRF), arobust calibration is established for everyformation investigated using a full-scalewavelength dispersive XRF (WDXRF).Reference material from NIST and theUSGS are routinely analysed to determineprecision and potential drifts of data. Forexample, the Montney Formation In AB/BCis based on over 250 calibration samples,

while other formations have calibrationsamples between 20-50 (e.g. Fig. 1-4)and is then used to identify the elementalrelationships between WDXRF and HHXRFto calibrate the HHXRF. Geochemicalsample analysis with the HHXRF is a fasterand cheaper means of collecting data.

The chemical elemental (XRF) andmineralogical (XRD) compositions andtotal organic carbon (TOC) determinedfrom high frequency analyses of wellcuttings, combined with mechanicalproperties determined with novelinstrumented indentation tests on cuttingsand rigorous modeling of reservoir andmechanical properties based on XRF andXRD data and pre-acquired core databasecan lead to a much better understandingon the lateral variations within a reservoir.The enriched information from cuttingsenables geologists and engineers to designoptimal stimulation and completionprograms based on effective ‘engineering’approaches instead of commonly-usedbut ineffective ‘geometrical’ approaches tomaximize hydrocarbon recovery while withminimizing costs.

A FOCUS ON CAPROCKCaprocks are non-permeable rock typesoverlying petroleum-bearing formationsof various compositions. Caprocks are

Figure 1 3: Calibrated handheld XRF profiledetermined by Trican (orange lone) and selectedWDXRF data points (Trican) in comparisonwith data collected by another laboratorydemonstrating a good fit between WDXRF dataand Trican’s HHXRF. The second set of datawas provided by another lab but shows a poorcorrelation, overestimating Si as a result of a poorcalibration. Considering that geochemical datais used to model rock properties and mineralcompositions, poor calibrations can lead tomarked errors in model outputs.

Figure 1 4: Calibration of handheld XRF data against a wavelength dispersive XRF unit of a formation inAlberta with limited core tests.


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expected to provide a seal for hydrocarbonmigration during completions of theunderlying formations. In shallowunconventional reservoirs, such as oilsands, mechanical properties of the caprockare critical. Mechanical testing of caprocksamples is challenging and regulationsregarding the requisite testing is not likelyto become any more lenient anytime soon.Truly the question to be asked is “how doI get the knowledge I need to ensure thata stimulation program will not result incatastrophic failure”? We all want to get themost out of our projects without harmingpeople, and the environment. Mechanicaltesting of caprock core can be plagued withpitfalls and projects can turn into moneypits if not properly planned. Data can bemisleading if not presented in a clear,

concise, and organized manner.

Trican Geological Solutions has developeda full suite of potential testing and coremanagement that can be customized tomanage the specific challenges inherentin the world of caprock testing. The TGSadvantage starts directly at the wellsite,with experienced geologists utilizing ourcustom-built air suspension transportsystem to ensure that core materialarrives at its destination in a safe, timelyand organized manner. Once the corematerial has arrived at the laboratory, fulldiameter scout scan CT can be performed.Computed tomography (CT) scanningand core imaging provide an invaluabletool for better understanding laboratorydata and for the screening of samplesprior to testing. Sample selection plays aparticularly significant role in the testingof caprock integrity, where microfracturesand rock fabric are of critical importancein these highly heterogenous deposits. Forminimal investment, a CT scout scan canbe used to investigate the suitability of aninterval for mechanical testing and allowfor qualitative analysis of the core prior toremoving it from the liner.

Once samples have been selected from CTimages and discussed with geological andengineering teams, preparation begins. Thepreparation of full diameter core sampleshas a significantly higher rate of success on

caprock cores when compared to pluggingprocedures, as less disturbance is inducedand there is no need for the introductionof fluids which could potentially damagesensitive clays.

With a full suite of geomechanical testing,Trican works closely with their clientsto ensure most applicable data possiblefor their testing budget. Triaxial testingis generally a large part of the requisitetesting, obtaining Young’s Modulus,Poison’s ratio, and compressive strengthunder varying stress states, temperatures,and preconditioning cycles. Thisinformation can be used to build Mohr-Coulomb envelopes, in-situ stress models,and determine changes in strength withchanges in temperature. Direct Sheartesting can be used on various sample sizesand shapes, which can allow for mechanicaltesting of zones that would not be suitablefor triaxial testing. Direct shear testingmeasures shear strength and modulus asa function of normal stress and can also beused for the definition of failure envelopes.

Every caprock is unique and requires athoughtful approach to designing a testingprogram. Whether the goal is to increaseproduction, comply with AER regulation,or simply understand the rock physicsof your reservoir our committed team ofexperienced geoscientists will consultwith each operator to develop a program

Figure 1 5: CT scanning used to select homogenouscaprock samples (glauconitic sand unit) fortriaxial testing. Features to note: using preliminaryCT scanning helps avoid low angle fractures(red arrow), and irregular bedding features (bluearrows)

Figure 1 6: Example of a Mohr-Coulomb failure envelope created from 4 triaxial tests from varying stressstates.



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that matches the data needs. Ultimately,precious capital is being spent to evaluatethe rock, and every operator deservesinput and transparency into the data beinggenerated.

Figure 1 7: Example of stress paths of triaxial samples with different confining pressures.The higher theconfining pressure the larger the slope of the loading curve, demonstrating sample stiffness increase withrespect to an increase in confining pressure.

Figure 1 8: Photographs of a clay rich caprock sample before and after triaxial testing. Material aftertriaxial testing is still viable for tests such as XRD,which allows for zonal identification and quality control.




October 16th - 20th, 2017 | Calgary, ABInstructor: David James

Course OverviewThis five-day school has been taught to Calgary,Houston and internationally based geologists and geophysicists for over 30 years and was initially designed as a mandatory course for all junior staff.Over the years it became apparent that more seniorG/G (and Engineers) could gain great benefit from re-examining the advances made in facies modeling,traces fossils, sequence stratigraphy and seismic geomorphology. Using a combination of lectures followed by core examination, all clastic depositionalsettings from the Western Canadian basin that contain hydrocarbons are discussed.

Emphasis will be placed on core description, identifying sedimentary structures, recognizing reservoir facies,sequence boundaries, flooding surfaces and most importantly, thinking geologically. Delegates will be exposed to a vast amount of core (600+ boxes) over 5 days. The ultimate product is the establishment of arobust stratigraphically and facies based exploration model to guide a drilling program. Core correlation andfield based exercises with data sets from the Alberta Basin and the international arena will be used to reinforce the concepts. The school concludes with a lecture on the controls of reservoir quality and how they relate to depositional setting and well productivity.

David earned his BSc and MSc from the University of Calgary during the 70’s and later, his doctorate from Oxford working under the supervision of Harold Reading. He has 35+ years of Industry experience. The first 14 years werespent at Esso/Exxon where he was introduced to sequence stratigraphy. It was at this time he started a 25+ year collaboration with Henry Posamentier, Mac Jervey, Dale Leckie and more recently Andy Pulham. After Esso, Davidserved in various roles such as Chief Geologist, Chief Geoscientist or Manager of International with Wascana/Nexen,Renaissance/Husky and Anadarko. In addition to his extensive experience in the Western Canadian Basin, McKenzieDelta and East Coast, David has spent many years in the International arena, especially the Middle East and UK. He isthe co-editor of CSPG Memoirs 15 and 18 on Sequence Stratigraphy and the Mannville Group respectively and has published many articles or abstracts on stratigraphy and sedimentology. As a consequence of his contributions, Davidhas repeatedly been selected as a distinguished lecturer for the CSPG in addition to being recognized with awards fromthe SEPM and AAPG. During his many years in industry, David has taught exploration, clastics facies, sequence stratigraphy and led field trips for several generations of geologists and geophysicists. Well over 1000 G/G have attended his Clastics Exploration school taught since the early 1980’s and a similar number of delegates with his Nautilus based Colorado Field trip, taught with Andy Pulham for over a decade. David was a Director and Vice Chairman of Geoscience BC, sat on several boards and lives in glorious retirement in Victoria where he plays golf verybadly.

Meet the Instructor

CSPG Member Rate $2400Non-Member Rate $2600

David has chosen to teach this class for the last time under the auspices of the CSPG asa thank you to the Society and to Industry.



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2017 STUDENT INDUSTRY FIELD TRIPBy: Jesse Schoengut and Vanessa Huey

The first Student Industry Field Tripwas run 40 years ago by a group ofgeologists who believed that the best

geologists are the ones who have seen themost rocks, and that students can learnmore from being surrounded by rocks thanby sitting in a classroom. Each year sincethen, students from across Canada havecome to Calgary for a two week crash coursein role of a petroleum geoscientist and thegeology of Western Canada. While parts ofthe trip have changed quite substantiallyover the years, the core parts of SIFThave remained the same: to provide thestudents with a fundamental backgroundof the petroleum industry; expose themto the geology of Western Canada; andprovide an opportunity to network withother University students and industryprofessionals

This year, 32 students from differentUniversities across Canada partook in SIFT2017 from April 30th to May 1st. Mirroringthe changes to the program itself, thestudent demography this year was differentthan in the past: SIFTEE’s this year werea combination of second-, third-, andfourth-year students, among whom someidentified as geophysicists and geologicalengineers! The students were kept extremelybusy over the two weeks, beginning withthe Icebreaker reception on the first night,and culminating with the ‘Wine & Cheese’Awards ceremony on the last night. Duringthe days, the students attended lecturestaught by industry experts, with topicsincluding petrophysical log interpretation,sequence stratigraphy, unconventionalresources, and production technology,and core workshops overviewing thedifferent play types in the Western CanadaSedimentary Basin. They also attended twofield trips: a day trip to Dinosaur ProvincialPark, and a four-day loop through theRocky Mountains. On the four-day, ourexperienced technical leaders show thestudents various play types and producingformations within Western Canada byshowing seismic lines, well logs, cross-sections and mapping, and then turn tothe mountains where world class outcrops

display these important geologic concepts.They also take a tour of a (learning) drillingrig at SAIT which gives exposure to theoperational side of the industry.

All of the learning they do during the day isaimed at setting them up for their eveningactivity: the Exploration Game. In teams offour, the students are given an initial sumof ‘money’ and start their own oil and gasexploration companies. They work throughdeveloping and expanding their land baseby bidding on land during land sales, drillingwells, making farm-in and other deals,and recompleting wells for bypassed pay.For most of the students, this is their firstexposure to the industry, so things like welllogs and the DLS land system are completelyforeign to them. The exploration game isconcluded by each team presenting theirfinancial summary, company strategy anda geological overview to a panel of industryjudges, who then award the Technical(Bill Ayrton) and Financial (Larry Strong)Awards to the teams. Mirroring industrytoday, we had the most number of farm inand land swap deals this year than we’vehave in years past! This year, the TechnicalAward went to Arin Kitchen (University ofRegina), Katherine Lazaruk (UBC), Laura-

Pier Perron Desmeules (University ofQuebec – Chicoutimi), and Adrian Oberland(Laurentian), and the Financial Award toDanielle Livingstone (University of Alberta),Dillon Langelaan (Acadia), Spencer Killins(Lakehead), and Kieran Tompkins (McGill).As seems to be the case with past years, thejudging was extremely close, and the judgeswanted to congratulate all the teams on a jobwell done!

Planning for SIFT begins well before thestudents arrive, and the logistics behindkeeping the students busy for two weeks isa large task. Thankfully, SIFT has a barrageof willing volunteers – many of whom areprevious SIFTEE’s, and a growing number ofnon-SIFTEE’s who never actually attendedthe trip. This year we were lucky enough tohave over 30 people on the planning andorganizing committee, and an additional40 people who gave lectures, seminars,ran the field trips, and volunteered at theExploration Game. We can’t begin to thankeach and every one of them enough for allthe hard work they put in.

SIFT owes a big part of its continual runningto the financial and in-kind support ofnumerous companies and individuals.

SIFT students at the AER Core Lab after core seminar.



The majority of SIFT is supported by theCSPG Foundation and its vision to supportUniversity Outreach programs whichadvance education and awareness of

petroleum geoscience. Financial supportfrom industry was strong this year, andsponsors included Imperial Oil, ProgressEnergy, Canbriam, Nexen, Murphy Oil,CNRL, Husky, and Saguaro. Industry alsostepped up in another way, as two SIFTstudents were hired through the SIFT jobprogram. The University of Calgary alsogenerously donated the lab space andmeeting rooms that were used over thecourse of the Exploration Game.

As SIFT looks ahead to next year andbeyond, it is important that the programadapts and changes along with industry inorder to remain a relevant and desirableprogram for both students and industry.We have already started to see some ofthis in changes to the topics of the lecturesand core workshops presented – Oil

Sands, Duvernay and Montney are moremainstream and conventional topics, whileCardium, Viking, and Leduc are moving intothe unconventional realm. Future seminarsmay include things like geomodeling,fracture techniques, and directionaldrilling, all of which are becoming a biggerand more influential part of our industry.

The 2017 SIFT committee thanks its’ generousvolunteers and sponsors, and congratulateseach 2017 SIFTEE for another successfulyear. May the memories, knowledge andfriendships forged during SIFT 2017 remainwith you for the rest of your career, as ithas with each SIFTEE in years past. We arealready looking forwards to planning the 2018program, and reaching out to each Universityacross Canada once again.

SOCIETY NEWS

SIFT students getting a geology overview at theMount Norquay overlook stop on the 4-day fieldtrip from leader Peter Fermor.

GEOCONVENTION 2017: FIELD TRIP FT2 “PROGRESS ANDCHALLENGES FOR CCUS IN ALBERTA AND CANADA”.

This field trip was held May 11, 2017.The trip included a visit to CMCResearch Institutes’ Field Research

Station in Newell County about 22 kmsouthwest of Brooks. The trip discussedaspects of Climate Change Science andMitigation Efforts related to capture andstorage in geological media in Alberta,with an emphasis on two globallyrecognized facilities. Kirk Osadetz (CMCResearch Institutes) discussed theirNewell County Field Research Station, asubsurface technology development anddemonstration project that injects smallvolumes of CO

2 from above to simulate

a potential leakage from a hypotheticalrepository below. The FRS is focused onthe development and demonstration ofrepository conformance and containmentof the inject fluids. It operates at a depthsimilar to in-situ bitumen operations,~300 m, and it is focused on subsurfaceimaging and detection that reduce storage,injection and extraction project riskswhile improving public and regulatoryconfidence in safe subsurface operations.The FRS operates as an industrial JIP. LucRock (Shell Canada Ltd) discussed the ShellQuest Carbon capture and storage project.QUEST captures more than one million

tonnes of CO2 per year from the Scotford

Upgrader located near Edmonton, Alberta,reducing the direct CO

2 emissions from

the Upgrader by up to 35%. Quest is a fullyintegrated CCS project, as it involves thecapture / transport / injection / storageof CO

2, and a measurement, monitoring

and verification (MMV) program. The CO2

captured from the Upgrader is transportedby pipeline ~65km to the injection wellswhere it is injected into the Basal CambrianSandstone (BCS), a saline aquifer located ata depth of about 2 km below ground surface.CO

2 injection started in August 2015, and

during its first year of operation the Questproject stored more than 1 million tonnesof CO

2.

Participants at the CMCRI FRS with Paul Cook(Lawrence Berkeley National Labs/UnitedStates Department of Energy) and Brian Mellor(Executive Director CMCRI).

Participants andencounters a local

resident, from timesgone by, at Dinosaur

Provincial Park, whereDinosaur Park Fm.

outcrops are similar tothe uppermost bedrock

succession in thesubsurface at the FRS.



Mark your calendars, and get ready for the 2017 CSPG Mixed Golf tournament on 25th Augustat Lynx Ridge Golf course. The four-golfer, best-ball tournament includes a round of golf, meals, plenty

of hospitality and good times, and a chance to network with your colleagues and industry sponsors.This year we trust that we return to the typical August golf, where the course is at its finest,

with the inviting fairways, smooth greens, spectacular mountains and the ever-beckoning waterhazards and sand traps to capture errant golf shots.

This is a fun tournament, with balanced teams that allow all golfers to contribute to the teamscore, while having a great time enjoying the day and the fellowship of golfing as a team, and

developing your network of geoscientists.

Please watch for further announcements, registration forms and information in theCSPG Reservoir, and make sure to register on-line at the CSPG website www.cspg.org.

Register early to avoid disappointment!

We thank our previous sponsors from 2016 and look forward to the return of members, guests andsponsors to enjoy the event. A big thank you to our continuing committee members, Darin Brazel,

Norm Hopkins, Jeff Boissoneault, and co-chair Brenda Pearson.

You can address registration inquiries to David Middleton at 403-296-8844 ([email protected]),or to Kristy Casebeer, CSPG Coordinator at 403-513-1233 ([email protected]).

If you are interested in sponsoring the tournament this year, please contact David at [email protected] or Brenda at [email protected].

David Middleton & Brenda PearsonCo-Chairs CSPG Mixed Golf Tournament

2017 – 28th Annual CSPG Mixed Golf TournamentAugust 25th, 2017



TECHNICAL LUNCHEON

Permian Basin (Prototype Super Basin) and Other Superbasins:DiscoveryThinking, Innovation and LessonsSPEAKERCharles Sternbach,AAPG President 2017-2018

11:45 amFairmont Palliser Hotel,Crystal Ballroom133 9 Avenue SW,Calgary, Alberta T2P 2M3

Please note: The cut-off date for ticket salesis 1:00 pm, five business days before event.September 5, 2017. . CSPG Member TicketPrice: $45.00 including GST. Non-MemberTicket Price: $55.00 including GST.

Each CSPG Technical Luncheon is 1 APEGAPDH credit. Tickets may be purchasedonline at www.cspg.org

ABSTRACTThe Permian “SuperBasin” of Texas and NewMexico is comprised primarily of a thicksequence of Permian sediments depositedin the foreland of the Ouachita-MarathonThrust Belt. It is a composite feature madeup of the better-known Delaware Basin, theCentral Basin Platform and the MidlandBasin. Although a prolific hydrocarbonprovince with productive wells dating backto 1921, its recent emergence has onlybeen since 2008. Perhaps most remarkablyand for a range of reasons, it has becomevirtually the only area of the United Statesthat has not experienced a decline of eitherdrilling or production in the midst of theindustry’s current low price environment.It is “super” in more than just a geologicalsense.

Charles will enlighten on what makesthis “superbasin” tick. He will includeDiscovery Thinking lessons from othersuperbasins and petroleum rich areas. Theaudience will be provided with geologicaland technological fodder that can be usedin the rejuvenation of the Western CanadaSedimentary Basin, a sister “superbasin”.

Charles began his career with Shell Oil ina variety of assignments between 1984 and1997. He managed an Exploration Office in

Houston for Tom Jordan 1997-2004. He isnow the President of Star Creek Energy inHouston. He begins his terms as Presidentof the AAPG in July 2017. He is perhapsbest known for his organizational role inthe establishment and continued successof the innovative “Discovery Thinking”sessions featured at each year’s AAPGAnnual Convention and Exhibition.

BIOGRAPHYCharles A. Sternbach has explored for anddiscovered Energy in the US and around theglobe for 35 years. He was Staff Geologistfor Shell Oil Company, ExplorationManager for Tom Jordan (Jordan Oiland Gas), President of First Place Energy(International frontier exploration) and iscurrently President of Star Creek Energy.Charles has a PhD (and MS) in Geologyfrom Rensselaer Polytechnic Institute anda BA in geology from Columbia University.He is also proudly a member of AAPG andCSPG.

Charles has focused his efforts onExploration Creativity, studying howexplorers and their teams have found giantfields. He created and leads the popularAAPG Discovery Thinking Forums whichhave been standing room only eventsat annual AAPG conventions in NorthAmerica (ACE) and around the world(ICE). These impactful programs integrategeology, geophysics and engineering intocase studies of business success.

There have been 18 Discovery ThinkingForums since 2008 with about 10,000attendees. About 115 speakers havepermitted their video presentations to beposted on the AAPG Search and DiscoveryWebsite with 40,000 viewings around theglobe. In addition, Charles created theAAPG Playmaker program in 2012. These 1day forums on exploration creativity havebeen presented 10 times in the US, Canada,and Europe. More than 1,500 professionalshave attended and presentations havereceived 10,000 web views around theworld. More of these forums are planned.

Charles believes case histories of successful

explorers and their discoveries is a short cutto wisdom. Every geologist around the globeraises the level of collective intelligence forall by sharing information and techniques.Critical insights fall into patterns that canbe recognized and anticipated. The legacyof exploration literature forms a syllabusfor future explorers. Technology enablespreservation and communication ofcritical knowledge via the internet throughprograms like Search and Discovery,Datapages, and GIS spatial relateddatabases. He is a co-editor with Dr. RobertMerrill on the fifth installment of the AAPGmemoir series Giant Fields of the Decade2000-2010 (Memoir 113, in press).

Charles resides in Houston, Texas. His wifeLinda is also a distinguished geophysicaladvisor. Charles is a leader in the globalgeological community: president-elect AAPG, past president Gulf CoastAssociation of Geological Societies, pastpresident Houston Geological Society,and past president of AAPG’s Division ofProfessional Affairs. He is an HonoraryMember of AAPG, HGS, and DPA.



CSPG PRESIDENT’S AWARD 2016, BRAD HAYESCSPG Awards Ceremony, 9 May 2017Ladies and Gentlemen, I am very pleased toannounce the CSPG President’s Award for2016, which goes to our Longtime, and NewHonorary Member, Dr. Brad Hayes

Criteria for Award: The highest volunteeraward presented in a year. It recognizes acurrent CSPG Member who has contributedto the society through outstanding service,and is chosen by the CSPG President at theend of their operating year.

The award may reflect service overlappingthe three year term centered on thePresidential year, as well as reflect thecumulative effects resulting from longtermand ongoing efforts.

You have already heard about the depthand breadth of Brad’s involvement with theCSPG from the Honorary Member citation,which is really impressive to hear whensummarized in its entirety. So I will focus alittle more closely on some of his volunteercontributions from the near term.

Brad has been impactful in a number ofareas recently; this includes participatingin the re-instatement of our HydrogeologyDivision as a keynote Technical Luncheonspeaker, by his involvement with the CSPGAmbassador Program including a numberof campus visits (which I will describein more detail below), also by acting as aliaison with affiliate Societies and agenciessuch as CSUR where he is Secretary andAPEGA where he is a Councillor, also bysharing his experience with upcomingstudents who are coming through on SIFT,and by being an advocate for the oil and gasindustry on campuses and as panelist andexpert witness in industry-related affairs;to this last point it is becoming increasinglyimportant to have individuals who arewilling and knowledgeable enough tospeak-out on behalf of what we do and howwe contribute to society.

For 2016 the CSPG Board was workingon strategic initiatives including aHydrogeology Division, as well asworkshops in the areas of Carbon Capture

and alternate energy such as Geothermal.To kick of the Hydrogeology speaker seriesBrad teamed up with Division Chair JamieWills and they delivered the inaugural talkat the November 2015 Technical Luncheon,entitled “The New Hydrogeology: RenewedImportance of Water to the PetroleumIndustry in the 21st Century”. This effectivelykicked-off the Division, and a number talkswere then rolled out for 2016. Water usein the industry has grown exponentially inrecent years, and Brad is an Industry leaderon this topic from his work as President ofPetrel Robertson, and it was important tohave a speaker of his calibre to start-up theDivision.

Then for January and March of 2016 Bradset-up two very significant AmbassadorProgram events at the University ofAlberta. Note, individual Ambassadorsare responsible for different sectors of thecountry, and Brad is the designated CSPGAmbassador to the Prairies. In January2016, the UA Department hosted a visitby training personnel from geoLOGIC,for instruction on industry-standard oiland gas database/mapping tools. ManyDepartments around the country usegeoSCOUT which is a portal into the oil &gas business for them. The event was verypopular, so as a follow-up Brad and theDepartment decided on conducting a one-day classroom seminar for senior studentslater in the semester. Using his contactsBrad then teamed up with CSUR ExecutiveVice-President Dan Allen, and they puttogether a program on unconventional oiland gas plays. A campus lecture hall wasbooked for an entire day, and there were30-35 students in attendance, with otherstudents and faculty circulating in andout. They were also joined by Mark Flint,CEO of APEGA, who spoke to the studentsabout APEGA, professionalism, careers andethics. Mr. Flint also stayed for a couple ofhours to soak in some of the lectures onunconventional plays in Canada. So, thiswas a fully integrated event, we have ascoordinated by our Prairie Ambassador,five different organizations involved,including the UA, CSPG, CSUR, APEGA,and geoLOGIC. This sort of collaboration

optimizes our resources and exposure, andalways leads to new opportunities, andBrad is one of the few persons around whocan bring such a diverse group together inthis manner.

Shortly thereafter I received, as Presidentof the Society emails from the DepartmentHead, Professor Stephen Johnston, andfrom the Associate Chair of UndergraduateStudies Professor Murray Gingras; lettersstating how useful the workshop was andthat they acknowledge the efforts made byBrad and the others.

I should mention that another exercisethey conducted during the workshop wasa discussion on contrasting film clips theywatched from anti-development advocatesand from pro-development advocates;asking the students to be objective indeveloping their views. So you can see thatBrad is striving to bring some balance to thediscussions about resource development,which in the popular media is not alwaysfairly treated – the students need a basisfrom which to develop rational views, andit takes someone with real experience toguide them and strike that balance. Also,Brad has been called as an expert witness

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and has also served as a strategic advisor tothe Premier of Alberta’s CompetitivenessReview, to Provincial and Territorialregulatory agencies, and as a member ofthe Expert Panel on Hydraulic Fracturing inNova Scotia.

Follow up to the UA event will includea Women in Geosciences lecture inSeptember, and planning has begun for a1-2 day core workshop at the University,and will look to invite participation with theAlberta Geological Survey.

More recently Brad has continued tocarry the torch for the CSPG and for theindustry. In February he travelled as CSPGAmbassador to Regina and to Manitoba.In Regina he met with geologists from theSaskatchewan Geological Survey to discusstheir representation at GeoConventionand at CSPG Core Conference; he thenmet with faculty and students at theUniversity of Regina, and delivered a talkentitled “Protecting the Environmentwhile Developing Unconventional Oil andGas: Because it’s 2017” to a substantialaudience (~30) at a late afternoon seminarsession; as you can see he continues toaddress both sides of the debate head-on,and strives to find a workable middle-ground. Then on February 16 and 17, hevisited the University of Manitoba, andwas enthusiastically hosted by Professorsand students alike, some involved inpetroleum-related research, he deliveredhis talk, several meetings were arranged,and he spent a full and productive two days– that’s a big time commitment.

I have gone into some detail here on this,but it’s important for you to hear this so thatyou can truly appreciate how impactful andrelevant these efforts can be. Back in 2001when Brad was President of the Society heinitiated University Outreach, and today weare hearing about some of the outgrowthfrom this action which is taking shape indifferent forms.

Brad, thank you for your dedication to theAmbassador program these last coupleof years, and the workshop and talks you

gave on campuses in Edmonton, Regina,and Winnipeg. Your ongoing work withSIFT is important, and the Luncheon talkyou gave to kick off the new HydrogeologyDivision is appreciated. Thank you forhelping to create a bridge between CSPGand CSUR, and between CSPG and APEGA.The improvement of communication issomething we at the CSPG need to continueworking on. Also noted is your willingnessto be an advocate for the industry, whichtakes courage and conviction stemmingfrom your true understanding of the issuesat hand. Most of all, thank you for being along-standing member and volunteer overmany, many years, it takes time, effort, andreal generosity to contribute at the levelthat you do. Your volunteer work has madean impact on the success of our society,on countless individuals and coleagues,and your efforts are admired by us all –CONGRATULATIONS!



H.M. HUNTER AWARDBackgroundThe H.M. Hunter Award was originallycreated to recognize CSPG members whohave contributed long term distinguishedservice to the Society. As such the focus wason volunteers more in the latter part of theircareers and who likely had served in a varietyof capacities. However distinguished serviceis not limited to long term service membersso the original concept has been modified toalso recognize outstanding volunteer effortsof the Society's younger members. The H. M.Hunter Award now recognizes:

• a longer term CSPG member (20+years)who has contributed to the Society on anon-going basis in a volunteer capacityin a variety of portfolios and/or singularoutstanding service. This would includean outstanding individual who has notreceived a major service award recently andif they have been recognized in the past,have contributed to provide great serviceto the Society since that time. Specialconsideration is given to those 'behindthe scenes' i.e. 'unsung heroes' whosecontributions have not been adequatelyrecognized. Such longer-term membershave gone above and beyond and by doingso have promoted our profession and theSociety.

• a shorter term CSPG member (10-20years) for exceptional performance, whohas gone above and beyond, a rising

star as a volunteer to the Society, andwho has demonstrated an outstandingcommitment to the CSPG.

Both awards are of equal merit and recognizeexceptional volunteer commitment tothe Society. The CSPG is built on a legacyof service by members and so strives torecognize and encourage such recipients.There is no restriction as to the number oftimes an individual may win this award. Nordoes this award have to be awarded in eithercategory each year or at all in the unlikelysituation of no worthy nominees in a givenyear.

The portal for nominations from themembership is the Society's website.Besides filling out the online nominationform, a letter of recommendation along witha citation of volunteer history is requiredwith a nomination.

History of the H.M. Hunter AwardFirst awarded in 2004, this award is namedafter Mr. H. (Harry) M. Hunter who was afounding member of the Alberta Society ofPetroleum Geologists. He had one of thelongest volunteer careers of the foundingmembers. Harry Hunter served as ASPGSecretary-Treasurer in 1929, as BusinessManager in 1935 and 1937, and as Presidentin 1939. Harry Hunter was the only foundingmember present at the final meeting of theASPG where they overwhelmingly agreed to

change their name to the Canadian Societyof Petroleum Geologists. This award isnamed in honour of Mr. Hunter's work in theearly days of the Society, on the Executiveand his subsequent volunteerism. Theaward is a wall clock chosen to represent thetime members have given to the Society. Theoriginator of the award, Astrid Arts, designedthe original clock along with the companySlateworks who made them. The currentversion of the award is a plaque-style, slate,wall clock with the CSPG logo in the centerand the name of the winner on a brass plate.

Winners of the H.M. Hunter Award2016 - Dawn Hodgins and Gordon Stabb2015 - Astrid Arts and Kevin Root2014 - Norbert Alwast

2013 - Ben McKenzie2012 - Lisa Griffith2011 - Timothy Bird and Graeme Bloy2010 - No award granted2009 - Peter Harrington and Peter Hay2008 - Gerry Reinson and Kirk Osadetz2007 - Bill Ayrton and Memory Marshall2006 - Jack Porter and Ian McIlreath2005 - Vittorio (Vic) Panei and Ashton Embry2004 - Leslie Eliuk and Clinton R. Tippett

Our 2016 Hunter Award Recipientsare:Gordon Stabb and Dawn Hodgins

Gordan Stabb

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Gordon Stabb is a consultant PetroleumGeologist with a 35 year professionalbackground in Western Canadian oiland gas exploration, development, andproduction. Gordon holds a Bachelor ofScience in Geology from the University ofToronto (1981), and is a practicing memberof APEGA; the Association of ProfessionalEngineers and Geoscientists of Alberta.

Gord joined the CSPG in 1981 and beganvolunteer service to the society in 1982.The CSPG committees to which he hascontributed include:

• The Publication Indexing Committee:(1982 to 2004)

• The Basin Analysis & Sequence StratigraphyDivision: (2002 to 2012)

• The Board of Directors Executive, Directorof Finance: (2013 to 2014)

These contributions represent 32 years (andcounting) of continuous volunteer serviceto the CSPG. In addition Gord has authoredor co-authored numerous technicalpresentations and publications as well asrepresenting our profession in the CanadianHeavy Oil Association. Gord is truly an un-sung volunteer who has worked tirelessly fordecades in furthering a variety of endeavorsthat advanced the society.

Dawn Hodgins

Dawn graduated from University of Calgaryin 2001, with a B.Sc. in Geoscience and in

2006 with a M.Sc. in Structural Geology.She started in the oil and gas industry in1998 working for a small junior oil and gascompany as a technologist while completingher undergrad. Throughout her grad years,she worked for mid-size and smaller O&Gcompanies before starting with ExxonMobilCanada West in 2002 and Imperial Oilin 2005. Throughout the years, she hasworked on many projects across Alberta,Arctic Canada and East Coast, as well ascontinuously volunteering for the society.

A crucial program that the CSPG makespossible every year through the EducationalTrust Fund is the Student Industry FieldTrip (SIFT). As an early attendee, SIFT gaveher a first glimpse into the world of oil andgas and it set her onto a successful careerpath. She promotes the idea that SIFTpositively enhances student’s perceptionsof the oil and gas industry and that it attractsamazing talent to our industry and society.Embracing the true spirit of volunteerismand “giving back”, she has volunteered asan important part of the committee for over15 years. Her volunteer time expanded in2012/2013 to include the CSPG Board asOutreach Director and in 2014 EducationTrust Fund Trustee.

Dawn is now lead Operations Geologist forthe Hibernia Platform in Eastern Canada.

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TRACKS CITATIONAlexis Anastas

Alexis began his career in geosciencedigging out Ordovician fossils fromthe cliffs of the Humber River Valley inToronto during high school in the 80’s. Thischildhood passion led to Bachelor’s Degreein Geology at the University of Toronto,and he then followed his soft rock passionto Waterloo, where he received his M.Sc.,studying the Silurian Bruce Peninsula. Aftertwo summers mapping with the OntarioGeological Survey, Alexis then took a Ph.D. at Queens University, on Oligo-MioceneCarbonates from New Zealand. Amongother experiences, working as a graduatestudent on an industry field trip to the Bayof Fundy illustrated the value of geosciencein the working world and inspired Alexis topursue an E&P career. The magnitude of theprojects, excitement of the evaluation, aswell as the immense technical and businesschallenges sealed the decision to join theindustry in Calgary.

Alexis started his career in Calgary withAmoco in 1997 and started volunteeringwith the CSPG on Continuing EducationCommittee. Later he worked on the 1999short course slate. With the BP merger withAmoco, Alexis travelled to work on theprolific Wytch Farm in England and spentmany weekends, and a few weekdays, on

the Jurassic Coast World Heritage Site. Afterreturning to Canada, Alexis joined the GasBusiness Unit to work on developmentgeology, foothills, and deep basin fields,wells and prospects. In 2003 Alexis left BPto join Devon Canada Corporation as acarbonate sedimentologist to support thecompany’s many projects in Alberta, BCand occasionally Brazil. It was at Devonthat Alexis had the privilege to work with thelate Graeme Bloy, who would later becomeCSPG’s President. Graeme imparted hisstrong belief in the vast potential of theAlberta Basin, the importance of rigorousmethodical work, and a passion for theDevonian and Mississippian carbonatesection. Alexis’ next move was to the RegionalExploration Group at Nexen and that iswhere he has been for 10 years evaluatingassets, generating prospects, and bid roundsin Europe, Africa and South America. Tryingto reconstruct the geology of basins with verylittle hard data was a humbling experienceand makes one cherish the Alberta Basin.

Alex has found his years in the industryhas been rewarding for the challenges andrewards found in the work, but also largelybecause of the interpersonal experience.Through the years and in different countries,Alexis has been fortunate to work andvolunteer with many collaborative, hard-working groups of positive, friendlyand thoughtful individuals of differentbackgrounds. Alexis looks forward to thefuture pursuing his passion of working ingeology, spending time with family andfriends, cycling, volunteering, and watchinghis children mature into adulthood.

Alex has received four Service Awards inhis 28 years of CSPG Membership. ThisTracks Award has been earned throughhis exemplary volunteering, as well as hisdedicated work as the Chair for ACE fieldtrips and the way he reconceptualized theway CSPG values it’s instructors.

David ClydeDavid Clyde graduated with a degreein Geology from University of BritishColumbia in 1979. He started his career

working as a wellsite geologist with ExLogfor a year, before joining PetroCanada. AtPetroCanada, he started off working on theHibernia oil field, before being transferedto the Arctic Region where he was involvedin the day to day drilling operation of thePanArctic Joint Venture. He finished hiscareer with PetroCanada in the WesternBasin. Eventually, David transitioned into the accounting field and currently is aController at Hawk Machine Works.

David’s first involvement with CSPG wasin 1983, when he was asked to give apresentation on the Geology of the SverdrupBasin and Hydrocarbon Potential to theparticipants of the CSPG SIFT program. Hebecame involved again in 2007, when hebegan serving as a communication directorfor the technical chairs and other variouscapacities. He was asked to join the JointAnnual Convention Committee as a boardMember in 2012, and he assisted with theJACC transition to the GeoConventionPartnership, where he served as a Directoruntil 2016. David is currently a Trustee onthe CSPG Foundation.

David has been awarded four Service awardsand be a constant presence in the MixedGolf tournaments for almost a decade.David Clyde has earned this Tracks Awardfor his decade of devoted volunteer work

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with the CSPG and his leadership withGeoConvention.

Ian McIlreath

Since 1976 Dr. John Harper first introducedIan McIlreath to volunteering for the Society,on the Technical Luncheon ProgramCommittee, Ian has volunteered in manycapacities. Most notably he was the CSPGPresident in 1983 at the same time as beingthe Technical Program Chair of the 1983Annual Meeting, the General Chairmanof GeoCanada 2000 (the MillennialGeoscience Summit), and the originator andearly organizer of GeoCanada 2010. Besideshaving chaired an additional 25 differentcommittees, and being an active memberof at least 15 other separate committeesthrough the intervening years, Ian has beenthe CSPG liaison to 6 different national andinternational organizations. He has playedan active role in organizing and chairingother conventions, convention technicalsessions, and special technical meetingsincluding the first carbonate core conference(when it was a separate fall event), as well asleading field trips into the Front and MainRanges. Ian chaired the CSPG-CSEG-CWLSJoint Annual Convention Committee (2007 –2009). Based on his experience and historicalperspective, various CSPG executives haveasked him to lead a number of in-depth taskforces to investigate specific issues of specialinterest to the organization, and to act as anadvisor.

For his volunteer efforts the CSPG has

previously recognized Ian with thePresident's Special Recognition Award,President's Award (3 times), H.M. HunterAward, Tracks Award (4 times), and with anumber of Service and Volunteer Awards.

This particular Tracks Award is in recognitionfor recently chairing the AmbassadorProgram; chairing the CSPG Awards TaskForce; serving on the Medal of Merit, R.J.W.Douglas Medal and H.M Hunter AwardCommittees; being the lead in organizing thefield trips and core conference for the CSPG-SEPM Mountjoy Carbonate Conference; andthree other commitments.

Alex J. MacNeil

MacNeil, Alex J. is a carbonatesedimentologist and stratigrapher currentlyat Osum Oil Sands where he was workedsince 2012. Although the focus of his workis reservoir characterization and modelingof carbonate-hosted bitumen in theGrosmont Formation, he is also an activemember on the Cold Lake Orion SAGD assetteam. Highlights of his time at Osum haveincluded being part of the team involvedwith the Grosmont Pilot at Saleski, whichoperated for nearly five years before beingsuspended in September, 2015, and beingable to conduct several weeks of field workin Montana on the Madison, which servesas an analogue for key Grosmont reservoirfacies. Prior to joining Osum Alex wasemployed at Imperial Oil where he workedon a variety of projects from conventionalproduction at Rainbow and Norman Wells

to Mackenzie Delta exploration.

Prior to working in industry Alexcompleted a Ph.D. thesis at the Universityof Alberta (2006) on the stratigraphy andsedimentology of the Upper DevonianAlexandra Formation in the N.W.T., andan M.Sc. thesis (2001) on near-surfacedolomitization processes in the CaymanIslands. Alex completed his B.Sc. Hons.degree at the University of Saskatchewanin 1998. He loves being in the field and hasworked in northern Saskatchewan for theSaskatchewan Geological Survey and theArctic islands (Prince of Wales, Somserset,and Devon) for Cominco and Noranda.

Alex is an active member of the CSPGwhere he currently sits as the Director forConferences as well as a member on theTechnical Luncheon Committee and anAssociate Editor for the Bulletin. For manyyears he has been helping to organize ashadowy group in the city known as theCarbonate Liars… He is an Associate Editorfor the Journal of Marine and PetroleumGeology and a member of the SEPM, IAS,and AAPG. In 2016 he was a co-chair forthe Carbonates and Evaporites theme at theAAPG Annual Convention and Exhibition,helping to organize eight sessions for themeeting. In 2015 he was a conferenceorganizer/technical co-chair for theinaugural CSPG-SEPM Mountjoy carbonateconference held in Banff. An SEPM-CSPGSpecial Publication on carbonate modelingand characterization is nearly completedfrom that event and will be published in thecoming months. This hard work, along withhis exemplary volunteering, has earned Alexthis Tracks award.

SOCIETY NEWS



MEMBERSHIP UPDATES

OBITUARIESRobert Dobson (Bob) OrrJuly 17, 1932 – Banff, AlbertaApril 26, 2017 – Calgary, Alberta

Robert D. (Bob) Orr passed away peacefully on April 26. A proud Albertan and Calgarian, Bobwas born in Banff, AB growing up in the mountains and foothills of Exshaw and Cochrane. Itwas here that his lifelong passion for the cowboy life was born with the Edge family, as washis love for science and geology. Bob graduated from high school in Canmore, then movedonto Mount Royal College, U.B.C. and then the University of Alberta where he graduated in1956 as a geologist. It was at Mount Royal that he met the love of his life, Margaret Matyas,marrying in 1956. Over the course of their 56 year love affair they created a loving householdthat highlighted learning, athletics, music, and good food and drink shared with family andfriends. Bob's successful business career began at Imperial Oil in the exploration departmentin Edmonton, then transferring to Calgary in 1968. In 1972 Bob joined Husky Oil as theirManager of Exploration, and in 1980 he became Husky's Vice President of Exploration. Duringthis time Bob also served as the President of the Canadian Society of Petroleum Geologists(CSPG) and was presented with honourary membership in 1982. He retired from Husky in1989, joining Marg as a full-time snowbird and golfer at their second home in Casa Grande,Arizona. Bob is survived by his son David, grandson Travis and wife Jenny and great-grandsonClark, granddaughter Megan; daughter Barb Long and grandsons Brendan and Connor. Hewas predeceased by Margaret in 2012, and his parents Bertha and Tommy Orr.

Elmer “Herb” HerbalyElmer “Herb” Herbaly passed away Sunday, February 28, 2016 at the age of 94. He was bornin Chicago to Hungarian immigrants. He served in the Army in Europe during World War II.While he waited to be sent back to the States at the end of the war, he took a geology class andknew that would be his life’s work. He earned Bachelor’s and Master’s degrees in Geology fromNorthwestern University. He spent a year working for the United States Geologic Survey. In1950 he began a career in the oil and gas industry with Gulf Oil Corporation. That December,he was set up on a date with Lorna Collett, a schoolteacher from Wisconsin who was workingfor Shell Oil Company. Within two weeks, he bought the rings, and they were engaged, makingLorna one of two women in the world who think of Casper, Wyoming as a city of mystery andromance. They married in 1951.

In 1957, they moved to Calgary, and in 1959 he and Paul Roston formed Panalta PetroleumsLtd., the first of several companies he built, followed by Elhexco Petroleum Ltd., HerbalyPetroleum Corp. and Herbaly Exploration LLC. In 1971 the Herbalys moved to Denver. In1978 his son David joined the business and over the years, running the business shifted aninch at a time from father to son. He continued to come in to the office until his final illness.

He was a member of numerous professional organizations in the US and Canada, includingAmerican Association of Petroleum Geologists, Canadian Society of Petroleum Geologists,Association of Professional Engineers and Geoscientists of Alberta, Rocky MountainAssociation of Geologists, Wyoming Geological Association and Geological Society of America.

Herb served on the board at Columbine United Church, on the All Veterans Honor Guard, andin various offices with the George Evans Post of the American Legion, the Pat Hannon Post ofthe Veterans of Foreign Wars, and the 89th Division Society of World War II. He was a memberof Columbine Kiwanis. He enjoyed gardening, travel, going out to lunch (with a glass of whitewine), but most of all his life with Lorna. They had an amazingly happy 64 year marriage.

Elmer is survived by his wife Lorna and son David. His daughter Jan died in 2006. Serviceswere held March 8, 2016 in Littleton, Colorado with burial at Fort Logan National Cemetery.



October 10-12, 2017Banff, AB Canada

Registration includesConferenceAccommodations 2 breakfast, 3 lunches Ice Breaker Conference Dinner

CSPG Members $1085 CADNon Members $1380 CAD

This year's Gussow Research Conference aims to address the holygrail of petroleum systems research!

We welcome a panel of expert speakers covering the physical principles ofpetroleum migration, geochemical (biomarker and isotope) tools, laboratory

experiments, numerical simulation, and case studies.

5 diverse sessions of world-class lectures and discussion will address petroleum migration from pore to basin scale,reservoir leakage, and entrapment in tight oil plays.

Organizing Commi ee:

Mar n Fowler, PhD.mar [email protected]

(Applied Petroleum Technology)

Milovan Fus c, PhD.milovan.fus [email protected]

(Natural Resources Canada)

Andy Mort, [email protected]

(Natural Resources Canada)

To view the technical program and to register

go to www.cspg.org/gussow2017


201362 CSPG Reservoir Mag July August

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