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GeoConvention & Core Conference

In This Issue... Technical Abstract Sneak Peek

Session Highlights

Core Conference

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57TH ANNUAL CSPG CLASSIC Elbow Springs Golf Club • Thursday June 21, 2018

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CSPG OFFICE

#150, 540 - 5th Ave SW Calgary, Alberta, Canada T2P 0M2 Tel: 403-264-5610 Web: www.cspg.orgPlease visit our website for all tickets sales and event/course registrations Office hours: Monday to Friday, 8:30am to 4:00pm The CSPG Office is Closed the 1st and 3rd Friday of every month.

OFFICE CONTACTSMembership Inquiries Tel: 403-264-5610 Email: [email protected]

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EDITORS/AUTHORSPlease submit RESERVOIR articles to the CSPG office. Submission deadline is the 23rd day of the month, two months prior to issue date. (e.g. January 23 for the March/April issue)To publish an article, the CSPG requires digital copies of the document. Text should be in Microsoft Word format and illustrations should be in TIFF format at 300 dpi., at final size.

CSPG COORDINATING EDITOREmma MacPherson, Communications Coordinator, Canadian Society of Petroleum Geologists Tel: 403-513-1230, [email protected] RESERVOIR is published 6 times per year by the Canadian Society of Petroleum Geologists. The purpose of the RESERVOIR is to publicize the Society’s many activities and to promote the geosciences. We look for both technical and non-technical material to publish.

The contents of this publication may not be reproduced either in part or in full without the consent of the publisher. Additional copies of the RESERVOIR are available at the CSPG office.

No official endorsement or sponsorship by the CSPG is implied for any advertisement, insert, or article that appears in the Reservoir unless otherwise noted. All submitted materials are reviewed by the editor. We reserve the right to edit all submissions, including letters to the Editor. Submissions must include your name, address, and membership number (if applicable).The material contained in this publication is intended for informational use only.

While reasonable care has been taken, authors and the CSPG make no guarantees that any of the equations, schematics, or devices discussed will perform as expected or that they will give the desired results. Some information contained herein may be inaccurate or may vary from standard measurements. The CSPG expressly disclaims any and all liability for the acts, omissions, or conduct of any third-party user of information contained in this publication. Under no circumstances shall the CSPG and its officers, directors, employees, and agents be liable for any injury, loss, damage, or expense arising in any manner whatsoever from the acts, omissions, or conduct of any third-party user.

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RESERVOIR ISSUE 3 • MAY/JUNE 2018 3

PRESIDENTClint Tippett

[email protected]

PRESIDENT ELECTMarty Hewitt

[email protected]

PAST PRESIDENTMark Cooper

Sherwood Geoconsulting Inc. [email protected]

FINANCE DIRECTORJim Barclay

[email protected]

FINANCE DIRECTOR ELECTRay Geuder

[email protected]

DIRECTORMark Caplan

Cenovus Energy [email protected]

DIRECTORAlex MacNeil

Osum Oil Sands Corp. [email protected]

DIRECTORKevin Parks

Alberta Energy Regulator [email protected]

DIRECTORMichael Webb

Suncor Energy [email protected]

DIRECTORLaurie Brazzoni

[email protected]

BOARD OF DIRECTORS 2018

EXECUTIVE DIRECTORLis Bjeld

[email protected]

CORPORATE SUPPORTERS Canadian Natural Resources Ltd. Geovariances Cabra Consulting Ltd. Mount Royal University RIGSAT Communications Birchcliff Energy Ltd. Earth Signal Processing Ltd. Enersoft Inc. Foothills Resource Services Husky Energy Inc. RSEG Saguaro Resources Schlumberger Canada Limited Secure Energy Services

Trican Laboratories Sproule Associates Limited Pulse Seismic Inc Canacol Energy Ltd. CAPL Clear Directional Drilling Solutions Ltd. Ember Resources McDaniel & Associates Consultants Ltd. MEG Energy Corp. Nexen ULC Roke Technologies Ltd. SeisWare Tangle Creek Energy Velvet Energy Ltd.

PERM Inc. Sensor Geophysical Ltd. CoreSearch NAL REsources TAQA North Ltd. Baker Hughes Calgary Core Laboratories Canada Midwest Surveys Point Loma RPS Energy Canada Ltd. Signature Seismic Processing Inc. XRF Solutions Ltd Kalahari Energy Corp. Shale Petroleum

BRONZE SPONSORS

GOLD SPONSORS

TITANIUM SPONSORS SAMARIUM SPONSORS

THANK-YOU TO ALL OF OUR SPONSORS

*As of April 1st

PLATINUM SPONSORS SILVER SPONSORS


TABLE OF CONTENTS

FRONT COVER

Coral – Bahamas. Upwardly branching Acropora palmata, more commonly known as Elkhorn coral, occurs in a tidal inlet associated with a fringing reef on Cambridge Reef, Exuma, Bahamas. Colonies of Elkhorn coral are fast-growing and branches can increase in length by up to 10 cm per year. It is one of the most important contributors to reef growth in the Bahamas whether that is by in situ preservation or through the accumulation of associated coral debris generated by destructive processes such as hurricanes. Photo: Wayne Laturnas

MAY/JUNE 2018 – VOLUME 45, ISSUE 3

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

MESSAGE FROM THE BOARD ................................................................................6

MESSAGE FROM THE EDITORS .............................................................................8

TALKING WITH ARCHITECTS ...............................................................................9

GEOCONVENTION GeoConvention Committee Biographies ...........................................................................12

Session Highlights

Integrating Geoscience to Optimize Unconventional Resource Plays Session ................13

Geoconvention 2018 – Duvernay I Technical Session ........................................................14

Geomodelling Session ..........................................................................................................15

New Conventional Plays and New Eyes on some Mature Plays ........................................16

Induced Seismicity – Modeling and Case Studies ..............................................................18

Technical Abstracts

Managing Induced Seismicity in Canbriam’s Altares Field in the Montney Formation, N.E. British Columbia – an Update. .................................................................20

Stratigraphic Patterns of Organic Carbon Enrichment in the Upper Devonian Duvernay Formation, Alberta ...............................................................................................23

Don’t Call it a Comeback – Delivering the Goods in the Alida Unit, SE Saskatchewan ...25

Building the 3D Provincial Geological Framework Model of Alberta: Integrating Decades of Geological Interpretation and Over Half a Billion Data Points to Create a Provincial-scale Geomodel of Alberta’s subsurface .............................................27

CORE CONFERENCE Session Highlights

Getting Back to Rocks 101 .....................................................................................................29

Technical Abstracts

East Shale Duvernay – What’s the appeal? ..........................................................................30

Dolomitization and Porosity Evolution – Petrographic Diagenesis of the Charlie Lake Formation, an Emerging Tight Oil Giant .......................................................31

Reservoir Facies of the Kesan Formation: Tight Gas Exploration in the Thrace Basin of N.W. Turkey .............................................................................................................32

Session Highlights

Inspiring Energy Innovation through the Alberta Energy Regulator’s Core Research Centre .....................................................................................................................35

Weatherford ...........................................................................................................................36

UPCOMING EVENTS Division Talks .........................................................................................................................37

SOCIETY NEWS Stanley Slipper Gold Medal 2017 - Alison Essery ...............................................................41

In Memorium .........................................................................................................................43

6 RESERVOIR ISSUE 3 • MAY/JUNE 2018

CSPG CONFERENCESBy Alex MacNeil

One of the most important and enjoyable aspects of the CSPG are its conferences and focussed

workshops. These present the opportunity for members to network, learn about different technical aspects from a wide range of topics, and to simply observe how other petroleum geoscientists are conducting business - fundamental parts of professional development. At the CSPG-SEPM Mountjoy conference this past June, Paul Mitch Harris – a veteran of the petroleum industry – remarked that if he learns one thing that he can apply back in

the office at each day of a conference, he considers it time well-spent. As simple as that sounds, it’s actually a pretty powerful statement and goal. And that’s the business justification for attending CSPG events – picking-up pieces of information, making discoveries, and broadening of skillsets such that you’re more effective back in the office (or research lab, the field, or classroom) as a petroleum geoscientist.

In my role as the Director of Conferences, my focus is the identification of topics suitable for high-impact conferences

and workshops. It may surprise many members to learn that my role does not include GeoConvention – as of 2013 GeoConvention has been an autonomous entity with its own Board that includes three CSPG appointees. Of course there is constant dialogue between the GeoConvention Board Members and CSPG Directors, but the CSPG Conference Director has limited involvement. Rather, my portfolio includes the annual Gussow Meeting, Mountjoy meeting (only held every four years), technical luncheons, and focussed workshops/small “one-off”

MESSAGE FROM THE BOARD

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conferences such as the Geothermal and Carbon Sequestration meeting held in 2016 (before my tenure). The technical program for this year’s Gussow Meeting on geomodeling is now posted on the CSPG website – be sure to check it out!

There are several aspects that impact the success of CSPG conferences – the subject matter must be timely and of broad interest, there must be a core group of technical chairs willing to volunteer significant amounts of time to pulling the meeting together, sponsorship is vital to keeping costs reasonable, and scheduling of the meeting and its location must be carefully considered. The significant downturn in our industry since 2014 has certainly impacted budgets which has made attending even luncheons challenging for many individuals. Another challenge, not insignificant, that has emerged over the last couple of years is competition for subject matter from other local professional petroleum

societies, reflecting the increasingly integrated nature of petroleum geology with geophysics and various engineering disciplines. This has translated into competition from other societies for people’s time, budgets for attending meetings, and subject matter. Going forward, members can expect to see more meetings co-hosted with other societies, which from a technical perspective can be quite valuable.

In 2017 we conducted a survey of the membership to identify potential themes for specialized conferences and workshops. To no one’s surprise, significant interest in themes related to unconventional resources was expressed. Significant interest in oil sands and operations was also expressed. Topics related to geomodeling are of significant interest and will be addressed at this year’s Gussow meeting in October. Various carbonate topics were covered in 2017 at the Mountjoy meeting in Austin, Texas.

Going forward – this is where the society needs your help! In this issue of the Reservoir look for the call for proposals for specialized meetings/workshops. Plans are being made for a workshop on advanced methods in core characterization to be hosted in March 2019, but we need some of our more experienced members and subject matter experts to step-forward as technical chairs for future meetings (including Gussow 2019). Is this you? Helping to plan a specialized meeting, and seeing it through to the actual event can be a rewarding experience and a milestone in one’s career while making a valuable contribution to the society. Check out the call for proposals and please feel free to contact the office, or myself, if you have any questions. As Director of Conferences I hope that we can continue to deliver specialized meetings and workshops that members find relevant, rewarding, and enjoyable!

MESSAGE FROM THE BOARD

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CONFERENCE ISSUE

After such a long winter I hope that with this issue we get some well deserved spring time weather to

usher us into summer. Firstly, a big thanks to the Convention Committees for agreeing to provide some technical sneak peeks in this issue. The Reservoir was working with Geoconvention and the Core Conference to showcase some of the exciting content of this year’s convention. Again, a big thanks to Dustin Menger, GeoConvention Executive Director who is celebrating his third year organizing Geoconvention.

I hope this Convention Themed Reservoir will raise some excitement for Geoconvention and the CSPG Core Conference. We highlight just some of the exceptional sessions and offer a few teasers from what I am sure will be some very well attended technical talks. It has been a rough ride for our profession during this recession but I would encourage everyone to try to attend. In my mind there is no better value for the number of talks and networking opportunities during these events.

I like to start this issue with a look at some of the exceptional individuals who have been working for the past year to bring the GeoConvention together. Following my chat with Dustin Menger, this issues Talking with Architects, there are two individuals that Dustin wanted to introduce as new additions to GeoConventions: Shelley Leggitt and Neil Watson. Shelley is new to the GeoConvention board, one of three board members representing the CSPG. Shelley has come to the table with great enthusiasm to make GeoConvention bigger and better by applying a strategic sense to

GeoConvention’s direction. Neil is new to the Planning Committee, and is currently the CSPG General Chair. Neil has brought a new focus and attention to the technical program; he has driven a full re-work of how the GeoConvention presents technical content. Additionally, I have asked the GeoConvention Session Chairs to give their perspectives on their respective sections. There are some very timely and pertinent talks on the Duvernay Formation and Integrating Geoscience analysis in the Montney; with the bonus of some “on the horizon” topics like Advances in Geomodelling, AI and Machine Learning.

Similarly, the CSPG Core Conference, organized by Adam Fraser, showcases some of the “usual suspects”: heavy oil targets of the McMurray, tight conventional Cardium, Viking and Falher formations. For those that lean towards the unconventional side of things there will be displays from the Montney, Duvernay and Horn River. On the international stage, a core from the Thrace Basin in Turkey will be presented. After taking in all the great core displays be sure to get in some quality networking at the time-honored tradition of the Core Meltdown.

I’m really looking forward to the next reservoir issue which will focus on some “GeoFun”. We have some great contributions from individuals who not only express a lot of passion for geology but also delight in the “lighter side” of our arguably “heavy” science.

Travis

Jason Frank Technical Editor for the CSPG Reservoir Sr. Geologist at Athabasca Oil Corporation

Jason Frank is a Professional Geologist who holds a B.Sc. and M.Sc. from the University of Alberta. He has over 16 years of experience in oil and gas including technical and leadership positions in exploration and development both on and offshore. Past experience includes Shell Canada Ltd., Burlington Resources Ltd., ConocoPhillips Canada Ltd., and Talisman Energy Inc. Jason has volunteered for the Society in the past, most recently chairing the Duvernay session at the Society’s annual convention (2014) and the Honourary Address Committee.

Travis Hobbs Technical Editor for the Reservoir Professional Geologist at Encana

Travis Hobbs is an undergraduate from University of Calgary with a graduates degree from Simon Fraser University in Geology. Professionally he has worked both domestically and internationally for 19 years in the Oil & Gas industry, and is currently celebrating 15 years with Encana. Industry roles have included development, exploration, management and business development. Prior to the Reservoir, Travis has held previous roles on convention committees and six years as the Chair of Continuing Education. As free time permits Travis enjoys cycling, cross-country skiing and teaching his two daughters violin.

MESSAGE FROM THE EDITORS


TALKING WITH ARCHITECTSDustin Menger, Geoconvention General ChairBy Travis Hobbs

Dustin Menger is a CSPG, CSEG and CWLS member and volunteer. Dustin has served on many

committees and initiatives including President of the Canadian Well Logging Society, GeoConvention General Chair and Industry Outreach projects on behalf of the CWLS.

Dustin received a Bachelor of Science in Economics and Bachelor of Science in Mathematics and Computer Science in 2002 from the Colorado School of Mines. After graduating Dustin entered into the oilfield service industry, working for both Schlumberger and Baker Hughes before investing in his own start-up cased hole wireline operation.

Dustin’s current role is Director of the GeoConvention Partnership where he manages the strategic direction of GeoConvention with the help of the GeoConvention board of Directors and partner societies. Dustin also oversees all operational aspects of the Convention, working with a vast team of volunteers to bring the annual convention to reality. In Dustin’s spare time he is a baseball coach for his two sons in Airdrie and manages their Minor Hockey Teams.

Questions more on a technical background:1) What were the influences on your work

during your early education/training? Was there something specific that drew you to the Energy Sector?

While I had (and still have) a passion of computer science, business and markets, right out of school, I could not see myself sitting in front of a computer all day, so when the opportunity to get dirty and work hands-on as a Schlumberger field engineer presented itself, I could not turn it down. It was not necessarily the energy sector that I was drawn to, but rather the adventure of a technical position, managing a field team

in remote locations that drew me to the industry.

2) With your computer science and mathematics background, I’m sure statistics and data analysis formed a large part of your training. If you’d be so brave as to summarize the Geoscientists that you’ve interacted with during your career? What general trends do they follow? Or are they a pretty abstract group or do you see some logic?

Ha! Good question. Computer scientists are a breed all their own as well where things are very much black and white with no room for interpretation – the answer is what is it and you can prove that it is what it is. Within the Geosciences, there is so much science and data that goes into conclusions, and even then, there is some gray area where interpretation, insight and experience is needed. I find geoscientists to be “outside the box” thinkers not only in profession, but in their day-to-day as well. I find that I am always learning new perspectives from the folks within the geosciences that I have the pleasure of working with; where things are very linear and black in white in my mind, our committees of geologists, geophysicists and petrophysicists introduce a whole world of color.

3) What were some of the learnings you had working with, and trying to meet the needs of a bunch of Geoscientists in your role with Service Companies? All positive experiences I assuming?

Positive indeed! I have found through my years on the service side that Geoscientists are very particular about deliverables and interpretation methods, but they have all been open to collaboration to give insights to the unknown. From running and interpreting dipole acoustic tools to formation imagers, answers are being

sought to help guide the next drill or completions strategy and there is no better feeling on the service side than walking in after a successful job with a thorough presentation of the data and findings that provide the insights that the producer is seeking.

4) Is there any guidance or advice you can give to individuals starting their careers working in the service sector?

There are three things I tell my kiddos before getting on the bus every morning – be respectful, be a leader and ask good questions. All three I would offer as guidance to anyone entering the service sector or any other role for that matter. I think the path that one takes in their life is guided by the connections they make; if a person is respectful and presents themselves as a leader, there will be many more paths that present themselves. I also truly believe that we are capable of learning a great deal from our peers, colleagues and advisors; we just have to be comfortable asking questions and approaching things with an open mind; success will come from learning from those who have been there and done that before, enriching and advancing our own knowledge set.

(Continued on page 10...)

TALKING WITH ARCHITECTS


Questions focused on GeoConvention:1) This is your third year being involved

with GeoConvention, what were some of the big learnings you took away from previous GeoConventions?

The biggest lesson learned from last year is that there is a thing as “too much diversity” of content within the convention. To counter the comments about GeoConvention always hosting similar content year after year, 2017 hosted the largest and most diverse program ever, however some of the sessions did not resonate with our delegates and while it was new, topical and very interesting, we found that we stepped out a bit too far, hence why 2018 integrates a focused theme/sub-theme format of technology, discipline and play-specific sessions.

2) What are some of the changes that we will see at this year’s convention?

The biggest changes this year will be on the focus of the technical program and the networking opportunities that our attendees have. We continuously take the feedback from our exhibitors, sponsors and attendees to help advance the Convention. In addition to the focused technical program, the biggest change will be with the lunches hosted each day of the Convention. Instead of GeoConvention hosting keynote lunches, this year, the lunches will be hosted by our partner societies and held off-site at venues close to the convention center.

3) What were the biggest changes and/or challenges you were faced with during this industry downturn we are experiencing? How is the convention committee adapting to provide a better delegate experience?

Certainly the biggest change with the downturn was the steep decline in the revenues streams, from sponsorship to exhibits and delegate pass spend; all areas took a big hit with the downturn. While we do not have control over the market influences, the committee took on an active role of managing the cost structure of the Convention to help ensure that despite lower revenues that the delegate experience was not compromised. Through these cost-

savings initiatives and the new structure of the Partnership as a stand-alone entity, costs have come down more than 50% over the last three years.

2016 was certainly a tough year, but 2017 saw a sizable rebound and with a focus on the technical content, the model has always been to build a program that makes the value of attending GeoConvention clear; with a topical and relevant technical program and meaningful networking opportunities, delegates will see the benefits of attending then exhibitors and sponsors will see the traction that GeoConvention is able to build, bringing them back into the fold as well.

4) Supervisors might not see the value of sending their employees to Geoconvention during these tougher times. How would you promote the value potential for delegates at this years GeoConvention?

The motivation of the GeoConvention 2018 planning committee was on the technical program – specifically a focused program based on relevant themes and play-specific work. For the dollar, I am not sure if there is better return on training budget, especially for our local audience. We have done everything we can to help support participation by keeping our pricing significantly lower than other geoscience conferences; the Canadian dollar alone helps with about 30% compared to conferences that charge in USD. GeoConvention has evolved to cover a wider variety of topics than ever before and we are very proud of the program the team has tailored for the 2018 show. We are confident that our delegates will return back to their office with new insights that will help them excel and bring positive return to their employer.

5) What aspects of the GeoConvention partnership are your favorite? Which parts of your role do you find less exciting?

There are a few parts of GeoConvention that I would consider my favorites:

• Working with the volunteer board, committee and session chairs is amazing. Everyone has such a

passion for the geosciences and the success of the convention; working with them toward a common goal is very rewarding as we all know how important GeoConvention is to the education landscape in Canada.

• The reward of the hard work when you see smiles at the convention – during the coffee breaks, on the exhibit floor; witnessing the connections people are making as a result of the convention.

The part of GeoConvention that I find more challenging is that the continuous improvement process really only has clear outcomes once a year; I am very much a person that likes immediate feedback and results, so having to wait a full year between implementing new initiatives to see how they play out takes me outside my comfort zone a bit.

6) Can you comment on your team? What kind of individuals have you gathered together to organize the convention? What traits do you look for?

I cannot say enough good things about all the people involved with GeoConvention. From our seven board members, 22 committee members, 92 session chairs and another 110 on-site volunteers, every single person has a passion for the geosciences and for the pursuit of building their knowledge base. So many unique perspectives and ideas all come together to make GeoConvention what it is. From small things like speaker gifts to the showcase stage and the layout of the mobile app to the overall design of the floorplan, the placement of certain sessions at certain times in certain rooms, all decisions are made by and with our group of volunteers. They are remarkable people that I am very privileged to have an opportunity to work with.

We have never really had to look hard for GeoConvention volunteers in the past; we have a good mix of people who have been helping for a few years and people who are new to the mix. If an individual is taking the time to seek out opportunities to volunteer with GeoConvention, I can almost guarantee that they are a good fit for the team as the have taken the initiative to step up and lend their time to success of the event.


(Continued from page 9...)


7) What are you most excited about for the 2018 GeoConvention? What would you recommend that everyone try to go see?

Honestly, I am really excited for all of it. If there was a part we were not excited for, we would likely remove it from the program! With that said, here is a quick list of the newest features that we are looking forward to:

Sessions• Machine Learning, Big Data and AI• Geomodeling• Duvernay• Spirit River and Depp Basin• Compare/Contrast North America

Unconventional Plays• Completions Technology• New Conventional Plays and

Revisiting and Extension of Mature Plays

Networking• Monday Night Icebreaker (with

complimentary drink ticket for delegates)

• Tuesday Night Networking (with complimentary drink ticket for delegates)

• CSEG Tuesday Let's Get Geophysical” networking lunch

• CWLS Wednesday “Refresh” networking lunch

Events• CSPG Keynote Luncheon, featuring

Deborah Yedlin • Challenge Bowl• Showcase Stage – with over 12

presentations already confirmed, the stage will be very busy this year!

8) In terms of sessions from 2017 to 2018 what trends have you noticed? What are the main (big) draws for the conference? Were there any surprises (i.e. rooms filled to capacity that you didn’t anticipate)? What themes did your session chairs target this year that are potentially different from last?

Trying to plan attendance of any particular session is one of the most difficult things we do. Room allocation is based around the anticipated popularity of any session;

upon identifying the sessions and after the first pass of distributing talks into sessions, the team meets for several hours to plan out the timing of the convention sessions – trying to be sure the most popular sessions are in the biggest rooms and that content at any given time does not conflict with complimentary content hosted at the same time.

A few sessions caught us by surprise last year – specifically the Getting more from your Data session and the Diversification of the Energy Industry session. Some we knew would be huge draws (Montney, for instance) but we did not know just how big they would be. The worst possible thing in my eyes is turning away delegates because a room is over capacity and in violation of Fire Code. We work very hard to try and make sure this does not happen.

9) Conventions are as much about networking as about technical content. What does GeoConvention have planned in terms of social events and general networking?

That’s right, we have really focused on the networking component of the Convention to bring as much social value as possible. We have a few new initiatives planned for 2018 what we are hoping build on the successes that we have seen in the past with our networking events – in particular, we are changing the format of the luncheons with the partner societies hosting their own lunch-time events for the 2018 show. The CSPG will have a keynote luncheon at the Palliser, featuring Deborah Yedlin, the CSEG will have a “Let's Get Geophysical” networking lunch at the Palomino Smoke House on the Tuesday and the CWLS will host “Refresh” networking lunch at the Bank and Barron – all venues within a quick walk from the Convention Center. In addition to the change in format of the lunch program, for the two networking events on the exhibit floor (Monday and Tuesday evenings) delegates will receive drink tickets. We are hoping this helps keep the party on the exhibit floor to ensure all of our exhibitors get good traffic and positive leads while creating a fun, lively atmosphere.

Questions centered on more general / personal items:1) Tell us something about the personal

side of Dustin Menger. What are your interests outside of work?

Growing up in Colorado, baseball was my thing, so I know nothing about hockey, but the thing I enjoy doing more than anything else is watching my sons play hockey while pumping the music during the breaks in action. It is so much fun to see their faces light up with smiles when we head to the rink . . . I mentioned to my wife the other day that their registration fee is our equivalent to buying season tickets to watch them play.

2) What does life right after a GeoConvention look like for you? I’m sure it’s a massive effort, what are your immediate plans for some R&R? Will you look to commit to another GeoConvention or are you considering passing the “torch”?

As long as the board and partner societies will have me, I am in for the long haul. I very much love meeting new people through GeoConvention; the volunteer committees have always been a pleasure to work with, bringing new ideas, perspectives and their own “flavor” to each event. I have developed a passion for planning an event that will return to the partner societies as much as we possibly can, to help them with their education and outreach initiatives. I very much believe in what the societies are bringing to the industry and I will continue to work to help ensure GeoConvention helps support these initiatives to the greatest extent possible.

Following the 2018 event, there will be a bit of down time for some camping, but the planning process for 2019 including the call for abstracts and solicitation for session chairs will begin before the end of May; while GeoConvention execution only takes three days, it truly takes a year to ensure every exhibitor, every sponsor and every attendee has a positive experience while at the show.



GEOCONVENTION COMMITTEE BIOGRAPHIESNeil WatsonNeil began his career of over 35 years at Gulf Canada where early assignments in the Foothills and Peace River Arch helped him develop a strong understanding of the relationship between structure and sedimentation. He honed his skills putting together regional evaluations as Lead Explorationist at a series of start-ups, contributing to their growth to mid-level producers. He has spent the last 10 years directing a diverse group of technical experts in a series of multi- and single-client consulting projects ranging from comprehensive basinal resource play studies to smaller scale M&A and prospect evaluations. Neil is continuing this work in his current role as Director, Geology at Enlighten Geoscience Ltd. Neil holds a B.Sc, in Geology from the University of Alberta. Neil volunteers as the CSPG general co-chair for the GeoConvention.

Shelley LeggittShelley Leggitt is one of three CSPG representatives serving on the Geoconvention Board and has been in the role since October 2017. Shelley is a Professional Geologist and was most recently the Finance Director and Finance Director elect for the CSPG (2016/2017). Shelley has 30 years of experience and is currently VP Exploration for NAL Resources. She has worked for numerous companies including PanCanadian, Encana, Enerplus and EOG Resources where she held various leadership roles. Shelley strongly supports training/mentorship opportunities and leading edge technical advancements for geoscientists which she hopes can be highlighted by participation in the GeoConvention.

GeoConvention 2018 is a must-attend event for access to latest innovations, discoveries and insights within the Geosciences, market and business analysis with international perspectives and research

Early Bird Registration NOW OPENExhibit and Sponsorship Opportunities Available

geoconvention.com

GEOCONVENTION


INTEGRATING GEOSCIENCE TO OPTIMIZE UNCONVENTIONAL RESOURCE PLAYS SESSIONEmily Duncan & Krista Beavis

Since 2016, operators in North America have faced numerous challenges resulting from a drop in

commodity prices. Those operating in tight and shale resources have been faced with the challenge of finding innovative solutions while keeping a close eye on the economics of these plays. Several industry partners have stepped up to this challenge by integrating geological, geophysical, mechanical, engineering and other related disciplines with conventional and emerging technologies to solve the problems of today.

In a three part series of talks, the collaborative team of renowned industry experts from Velvet Energy will present on their work in the Montney at Gold Greek. Marco Perez, Pippa Murphy and Andrew Iverson will demonstrate how they have pushed the limits of their respective data sets by integrating the seismic, geology and engineering, with the goal of establishing “a geologic model with production relevance addressing fracture geometries and flow performance”. The back-to-back talks will run sequentially in the session, with each talk focusing on a different aspect of the journey from seismic to stimulation. In the first presentation, the authors will focus on the seismic attribute workflow that was developed to ensure reliable estimation of mineral content from pre-stack seismic data and inversion. As part of this workflow review, the control steps that were undertaken to ensure seismic amplitude preservation will also be discussed. In part 2, the reservoir characterization workflow will be reviewed. The authors investigate the relationship between seismic attributes and reservoir properties using empirical and rock physics trends. They also exploit seismic anisotropy to image subtle faulting as part of the structural interpretation and use microseismic data to complement this interpretation after stimulation. The final talk in the series will address the inputs to the 3D geocellular model and how the team at Velvet improved their confidence in the

description of the subsurface. Descriptions of how log data, core analysis, NMR data, FMI interpretations etc. were incorporated can be expected from this presentation. The series is summarized by testing the integrated subsurface interpretation through hydraulic fracture modelling to visualize the rock response to hydraulic fracturing parameters.

Those who have worked to characterize and develop shale resource plays know there are many challenges, including fracture design, horizontal placement, optimization, and others. Satinder Chopra and Ritesh Kumar Sharma from TGS Canada Corp. will expand on the challenges in characterizing shale resource plays, and elaborate on why “integration of different disciplines, that include geology, geochemistry, petrophysics, basin and fluid migration modeling, reservoir engineering, drilling and completions” can ultimately lead to maximizing the number of high-performing wells.

Focusing on one of the challenges facing operators today, geosteering, Kuvaev et al. from ROGII Inc. have studied how technology and approaches have evolved in recent years to become “game changers in some conventional and unconventional plays, enabling operators to drill more cost-effective wells while increasing EUR.” They will focus on innovations that can be grouped into four categories, ultimately improving overall economics of these plays, while reducing surface footprint.

Another challenge in developing unconventional resources is hydraulic fracture design. This challenge is heightened when in the vicinity of neighbouring depleted zones and previously stimulated reservoirs, due to the effect fluid can have on hydraulic fractures. Ardakani et al., with ESG Solutions, will discuss “the influence of the depleted zones and completion sequence on the fluid- vs stress-driven

and spatial distribution of deformed rock volumes.” They will show how “the combination of PI (Plasticity Index), SI (Stress Index) and DI (Diffusion Index) can be used to categorize fluid-driven versus stress-driven processes” by way of a case study from the Midland Basin.

Basement faults can act as fluid conduits thus improving reservoir quality, but they can also be reactivated by hydraulic fracturing resulting in induced seismicity. As Mark Robert Taylor with Shell Canada Limited will show, “understanding the complex history of recently active faults is imperative to optimally drill, complete and space wells economically and safely in some low permeability reservoirs.” Using an example from the Horn River Basin, Taylor will describe how various data sources, including log, core, pressure, temperature, gas composition, production and completion reports, seismic, surface topography, magnetic and other publically available data can be used to understand shale reservoir permeability and potential challenges for operators active in these resources.

We are thrilled to provide a platform for these integration leaders to share their learnings at the2018 Geoconvention. Join us for the afternoon of May 9 in Glen Room 208-209.

BiosAs one of the session co-chairs, Emily Duncan is an advocate for collaborative and integrated approaches to subsurface problems in industry. Following her graduation from the University of Western Ontario (BSc Geophysics) Emily has gained over 17 years of experience in oil and gas exploitation and exploration geophysics. She has worked at several companies throughout her career, ranging in size from small start-ups to large, multi-nationals. Currently, Emily is employed at Suncor where she recently

GEOCONVENTION SESSION HIGHLIGHT



moved into the role of geophysicist for East Coast Frontier Exploration, following her three and a half year tenure on the Oil Sands and In Situ Emerging Projects team. Her main geophysical interests include reservoir characterization, seismic inversion, quantitative interpretation, integrative work, structural interpretation and acquisition survey design. Emily is a member of SEG, CSEG, EAGE and APEGA where she is a registered Professional Geophysicist. Outside of the office, Emily enjoys camping, biking, skiing, snowshoeing and fishing with her two children.

Krista Beavis is currently working with a multi-disciplinary team to better understand how current subsurface energy development can be used to understand potential future surface expression at the Alberta Energy Regulator. She is passionate about true collaboration to achieve positive outcomes for the province. Krista graduated from the University of Calgary with a BSc. in Geology, and Applied & Environmental Geology in 2007. She has since worked in multiple sectors of the industry in Alberta, from exploration to remediation, and currently regulation. Krista is registered as a Professional Geologist with APEGA, and holds memberships with CSPG and CSUR. In her time away from the office, Krista enjoys traveling, cooking and baking, hiking, knitting, gardening, and adventures with her puppy.

GEOCONVENTION 2018 – DUVERNAY I TECHNICAL SESSION Melik Smaili

According to the Alberta Energy Regulator (AER), the Duvernay Formation covers an area of

approximately 130,000 square kilometers, or the equivalent of 20% the area of Alberta! With such a vast scope, the Duvernay is emerging as one of the most attractive unconventional shale plays in North America.

Renowned as a “world-class” source rock, and to have charged historic conventional plays across the Western Canada Sedimentary Basin, the Duvernay has now (since the beginning of the decade) become one of the main unconventional reservoir targets itself. The AER estimates total in-place resource ranging from 350 to 540 trillion cubic feet of natural gas, 7 to 16 billion bbl of natural gas liquids (NGLs), and 44 to 81 billion bbl of oil.

In the last few years, industry exploration and development activity, along with extensive research in academic centers have contributed to significant progress in understanding the key parameters driving this play. Despite lacking in thickness when compared to other leading unconventional resources such as the Montney, the Duvernay compensates with its organic- and liquids-richness. In fact, the Duvernay’s liquids-richness, whether in the form of oil, condensate, or NGLs, has allowed industry activity to remain afloat during the latest challenges with the low commodity price environment as operators positioned themselves to realize the potential of this resource.

The Duvernay is a complex formation and it has taken a large amount of well, seismic, and production data to delineate and narrow down on its “sweet-spots”. Understanding its technical parameters, implementing optimized drilling and completions technology, along with continuous improvements in cost savings, will be key for the economic success of the play.

The agenda of the Technical Session on the Duvernay at the GeoConvention 2018 is rich and diverse. The first topics will focus on reservoir characterization and discuss the essence of the Duvernay’s organic-richness. Followed by talks showing how sedimentary facies, geochemical compositions, and thermal maturity variations can influence the geomechanical properties of the Duvernay, and discuss ways to positively impact completions and consequently production. Lastly, the session will close with a case-study demonstrating how the integration of seismic data can add significant value in mapping structural discontinuities, and their potential impact to induced seismicity.

If you are eager to know how far we have come in unlocking the Duvernay’s secrets, please join us the afternoon of May 7th in Glen Room (201-204) at the Telus Convention Centre for the Technical Session on the Duvernay.




GEOMODELLING SESSION Weishan Ren & Aurelien Pierre

3D geocellular models have been considered as the industry standard for estimation of hydrocarbon volume

in place, and are the fundamental basis for oil and gas resources development plans for several decades.

Geomodelling is a critical bridge between G&G and reservoir engineering. All the geological information and data are converted to a numerical model that can be utilized by reservoir engineers to evaluate the assets and design the reservoir development. However, due to the huge amount of subsurface data in the Western Canadian Basin and limited computational power in a low oil price environment, geomodelling has been underused for business oriented decision making in many projects in the past.

With the development of advanced geomodelling technology, more mature (and user-friendly interface) 3D geo-modelling software, and the significant improvement on computing power, Canadian oil and gas industry is now increasingly interested in applying numerical modelling concepts and techniques to various plays in a variety of ways.

This geomodelling session aims at promoting advanced geomodelling technology and practical applications with real case studies and key learnings, particularly, focus on incorporation of multiple sources of data to build realistic geological models, and on smart ways of using the geomodels to help optimize the efficient and responsible development of oil and gas resources.

In this session, we are delighted to showcase 6 presentations: 5 case study and one research paper. Firstly, we will learn about the 3D Geological Model of Alberta presented by Mrs. Paulina Branscombe from AER. The Geological Framework project of Alberta Geological Survey (AGS) has been designed using an evergreen modelling approach. It can be used for

basin-scale geological investigations within the Alberta portion of the Western Canada Sedimentary Basin. The 3D Provincial Geological Framework Model of Alberta is being used to support science based decision making at the AER and acts as the geological foundation to inform regulatory decisions related to the management of the subsurface. This work not only enables AGS to deliver geoscience information to a variety of stakeholders in a new and visually stunning way, but more importantly allows us to deliver information in a useful and easy to understand format.

Secondly, we will have one talk on modelling for heavy oil by RWS Geomodeling Ltd. & PTTEP CANADA Ltd, presented by Dr. Weishan Ren “Realistic geological modeling of Mariana Thornbury Oil Sands reservoir’. This geomodelling project has utilized well data, seismic data, geological conceptual models, and trend models. Geostatistical modeling methods were used for data integration with a good handle of different data scales and different data qualities. 100 realizations were generated for each parameter to access the associated geological uncertainty. Iwuoha et al. from University of Calgary will present on “Inverse reservoir property estimation and artificial neural network-assisted 3D modeling of the Montney Formation, Alberta”. The more detailed perspective of the 3D distribution of matrix properties and potential secondary porosity development presented in this research may yet hold the key to advancing our understanding of challenging issues such as static fluid phase distribution in the Montney Formation.

Two talks from Repsol Oil & Gas Canada will be presented by Dr. A. Pierre and Dr. B. Emmerson on deep basin play and Duvernay respectively. One talk will prove that the use of simple geomodels has significantly enhanced our ability to drill more complicated targets with greater reliability. The second talk will discuss modern geomodelling tools which allow for quick turnaround when new data is integrated, and outputs usable results for

comparing production data with reservoir characteristic data. Risk and uncertainty analysis are performed, and ultimately “Sweet Spot” mapping can be derived from a combination of modelled properties.

The last talk by S. Gholinezhad et al. from University of Calgary will explore the use of Quad-Tree decomposition for permeability upscaling. The Quad-Tree decomposition method is extended to unstructured oblong grid blocks for upscaling of absolute permeability in 2D heterogeneous thin stratified reservoirs with anisotropic permeability. The simulation results before and after upscaling are then compared in terms of accuracy and computational efficiency.

Please join us for the session named “Geomodelling”, Wednesday, 8:20 - 11:50 am, Telus 106, if you have any questions, please feel free to contact session chairs: Weishan Ren & Aurelien Pierre ([email protected] or [email protected]).



NEW CONVENTIONAL PLAYS AND NEW EYES ON SOME MATURE PLAYSDavid Robinson & Behrooz Hosseini

The Western Canadian Sedimentary Basin has undergone several resurgences of activity over its

long history. The most recent surge has been partly related to the advent of multi-stage fracturing of horizontal wells in unconventional plays. Since 2007, there have been a total of 174,832 wells drilled in the Western Canadian Sedimentary Basin. About 38.5% or 67,295 horizontal wells have targeted dozens of different horizons in the Basin. The question is how to focus your efforts when there are so many targets to choose from?

The bar graph below shows the distribution of horizontal wells by target drilled since January 2017. There has been a broad range of play types from shale to tight sand and carbonate. Activity is driven primarily by economics and access to capital, but our industry has a history of building off of other company’s successes. In the last year there has been a tremendous push towards oilier targets given their relative economic merits. The Viking shallow oil play has been targeted 8,282 times since January 2017 and so makes up over half of the Lower Cretaceous targets identified in the graph. The Mississippian play has also been targeted over 8,000 times primarily in Saskatchewan.

So how do you focus your attention if you are late to the game and missed the land grab with the industry darling horizons? This

session is intended to offer some insight to several plays that could pick up steam in the coming year and that are not discussed in the Montney or Duvernay sessions. As always, a good knowledge of analogues is helpful to leverage a quicker understanding of a new target. A look at what has transpired in the lower 48 over the past ten years shows us that most of the recent reserve additions are in identified plays that have been added onto through field extensions and modern drilling and completion techniques (EIA graph below). In other words, operators are not reinventing the wheel. They are back to the same basins and the same rocks that have driven their industry since its inception.

Canada’s data shows similar trends aligned to the latest technology change. Alberta for example, underwent significant growth in reserve additions especially in 2012, but the rate of increase in reserve additions has fallen more precipitously than observed in the Lower 48 area of the United States. Lack of activity has forced this drop that is driven by relative economics and politics. Canada is being



challenged to compete with the American juggernaut. To do this successfully we need to make better decisions that lead to more economic projects. There should be a good relationship between better technical understanding and better results.

It is important to remember that Alberta and by proxy, Western Canada has no shortage of resource outside of the Heavy oil trend. The latest resource picture from May 2017 by the AER suggests large untapped oil resources through the entire geologic column. It is a particularly impressive resource in the Cretaceous horizons that are the focus of some of the talks given in this session.

Talks scheduled for this session are aimed at taking a technical look at some recently active plays to help us gain insight into reservoir characterization of targets not covered by other sessions. Talks include a revisit of the shallow gas model for glacial deposits in Western Canada that are reasonably cheap to drill or recomplete in wellbores scheduled for abandonment review. We have also scheduled a couple of talks that look at the subtleties of chasing the Lithic Glauconite play in southern Alberta, comparing two different operator’s techniques in this tricky play type. For something completely different, there is a presentation that will shed some light on the Helium potential of the Western Canadian Sedimentary Basin. Helium commodity prices are currently attractive enough that this play type could develop into something highly prolific. The Clearwater Formation at Marten Hills sets itself apart from many other Clearwater reservoirs because the oil flows without the need for thermal or chemical stimulation and is still relatively shallow. Finally, we will see the session rounded out with a look at Saskatchewan. The buried hills of the Lower Cretaceous Atlas Member drive home the importance of detailed lithologic mapping. Some recent mapping of the Mississippian Alida Unit makes a strong case for revisiting old fields to identify highly economic infill opportunities.



INDUCED SEISMICITY – MODELING AND CASE STUDIESJohn Nieto & Sepideh Karimi

We invite you to attend the technical session on “Induced seismicity – Modeling and Case Studies” at the Geoconvention 2018. Induced seismicity is clearly a by-product of hydraulic fracturing and water disposal (injection). In this session, we bring together leading-edge presentations from various experts to better understand and predict induced seismic events. The topic is addressed from different angles including, the latest geomechanical research, fracture network analysis and pioneer case studies on induced seismicity monitoring, prediction and mitigation.

We expect that the range of perspectives presented, from industry, to government and academia, will shine a light on this important subject, while providing insight into understanding and mitigating the associated risk. These papers are highlighted in the abbreviated summaries below:

Understanding shear behaviour of a rough joint using surface topography scan and numerical simulation Qi Zhao and Giovanni Grasselli, Department of Civil Engineering, University of Toronto, Toronto, ON, Canada

“In this study, we combine rotary shear test, surface topography scan, and numerical simulation to investigate shear behaviour of a rough joint. The simulation results qualitatively captured the realistic emergent rock mechanical and frictional behaviours and suggested that surface geometry (i.e. roughness) controlled the initiation stage of slip.”

What Can Discrete Fracture Network Analysis Tell Us About Induced Seismicity In The Montney Formation? Steve Rogers, Golder Associates Ltd.

“The increasing occurrence of induced seismicity at felt magnitudes and above, is

well documented (Atkinson et al. 2016, Bao and Eaton 2016). In the Western Canadian Sedimentary Basin and particularly the Montney Formation, the majority of the observed events have been related to hydraulic fracturing operations. This is in contrast to the widely reported events in Oklahoma, where sustained wastewater injection has been linked with seismicity up to magnitude 5.7 near Prague in 2011 (Walsh and Zoback 2015).”

Managing Induced Seismicity in Canbriam’s Altares Field in the Montney Formation, N.E. British Columbia – an Update Brad Bialowas, Bogdan Batlai, John Nieto, Graham Janega, Canbriam Energy Inc

The Montney formation in British Columbia and Alberta has gained prominence in recent years due to the exploration and production boom which has yielded more than 3.5 billion bcf/d in production output and in excess of 440 TCF of reserves. It is one of the largest unconventional plays in N. America, covering 130,000km2 with 5600 wells drilled to date. The figure below, illustrates the Montney reservoir trend and Canbriam’s position in Altares in N.E. British Columbia. Canbriam is a private company currently with 40,000Boe/d producing capacity and a deep inventory of over-pressured, liquids-rich locations with stable, low-decline. The map also highlights some of Canbriam’s seismometer and accelerometer arrays in North Altares.

The key to understanding Induced Seismicity is a thorough understanding of the subsurface. This presentation describes the multidisciplinary integration at Canbriam which has led to the creation of an Altares-specific Induced Seismicity traffic light protocol based on ground motion, rather than the seismic event’s magnitude. The work integrates the subsurface reservoir characterization, including fault/fracture identification to assist in prediction of Induced Seismic events

during well completions. Operationally, Canbriam has RTC or request to complete meetings, which include full integration of engineering and operations. Decisions in these meetings are relayed to the field to ensure any potential risks such as inter-well communication potential, casing deformation and Induced Seismicity are well understood. 5 fracking case studies are presented which demonstrate the predictability of induced seismicity in an operational setting.

Induced Seismicity in the Doe-Dawson Area of British Columbia David McHarg, Tourmaline Oil Corporation and Paige Mamer, Itasca-IMaGE

“The Doe-Dawson area within the Montney play of British Columbia has experienced induced seismic activity in recent years. In response to these events, Tourmaline Oil Corp. installed a permanent, low frequency geophone array along with surface accelerometer(s) to better understand this phenomenon. This more sensitive, localized array has detected thousands of events to date and is providing significant insight and more suitable datasets for analyzing this problem further.”

Tony Creek Dual Microseismic Experiment (ToC2ME)David W. Eaton, Nadine Igonin, Andrew Poulin, Ron Weir, Hongliang Zhang, Scott Pellegrino & German Rodriguez Department of Geosciences, University of Calgary

The Tony Creek Dual Microseismic Experiment (ToC2ME) is a field program that employed a diverse set of sensors to record a hydraulic-fracturing completion program at a 4-well pad west of Fox Creek, Alberta. The acquisition systems consisted of a 68-station shallow borehole array, six broadband seismometers and one strong-motion accelerometer. This paper summarizes progress in processing and analyzing this dataset, which yielded a substantial record of induced seismicity



up to MW 3.2, including over 4,000 events with well determined hypocentres. The largest events have strike-slip mechanisms and clustered above the treatment zone, along a well defined N-S lineament. Several other event clusters are more diffuse and have distinct magnitude characteristics and mechanisms. Horizons extracted from

3-D seismic data reveal several structural fabrics that are subparallel to event clusters, although the microseismic lineaments do not appear to correlate exactly with seismically imaged features. The ToC2ME dataset forms the core for an integrated suite of co-ordinated academic research projects that include construction of a

regional geomodel using publicly available data, reprocessing and interpretation of co-located multicomponent 3-D seismic data, development of innovative microseismic processing methods, and geomechanical studies including laboratory analysis.


Our mission is: To advance the professions of the energy geosciences - as it applies to geology; foster the scientific, technical learning and professional development of its members; and promote the awareness of the profession to industry and the public.

CSPG is a not-for-profit corporation registered under the NFP Act.

Directors hold office for two years; commencing December 2018. Nominations for Directors close September 14th, 2018.

CSPG is seeking nominations for: President Elect – who will continue to serve as President in the 2nd year and Past President in the 3rd year

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Four Directors At Large – CSPG is seeking directors to fill portfolios such as Conferences, Education, Outreach and Publications

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1. Submit the Nomination Form for consideration to the CSPG Nominations Committee (shorter process whereby your nomination is considered).

2. Complete the Nomination Form requiring 25 Voting Member signatures. Your candidate will stand for election.

Deadline for submission September 14th, 2018 to [email protected] RE: CSPG Board Nomination

Please direct any questions to Lis Bjeld, CSPG Executive Director at 403-513-1235


GEOCONVENTION TECHNICAL ABSTRACTS

MANAGING INDUCED SEISMICITY IN CANBRIAM’S ALTARES FIELD IN THE MONTNEY FORMATION, N.E. BRITISH COLUMBIA – AN UPDATE.Nieto, J. Bialowas, B. Batlai, B. Janega, G. Canbriam Energy Inc.

Summary The Montney formation in British Columbia and Alberta has gained prominence in recent years due to the exploration and production boom which has yielded more than 3.5 billion bcf/d in production output and in excess of 440 TCF of reserves. It is one of the largest unconventional plays in N. America, covering 130,000km2 with 5600 wells drilled to date. The figure below, illustrates the Montney reservoir trend and Canbriam’s position in Altares in N.E. British Columbia. Canbriam is a private company currently with 40,000Boe/d producing capacity and a deep inventory of over-pressured, liquids-rich locations with stable, low-decline.The map also highlights some of Canbriam’s seismometer and accelerometer arrays in North Altares.

The key to understanding Induced Seismicity is a thorough understanding of the subsurface. This presentation describes the multidisciplinary integration at Canbriam which has lead to the creation of an Altares-specific Induced Seismicity traffic light protocol based on ground motion, rather than the seismic event’s magnitude. The work integrates the subsurface reservoir characterization, including fault/fracture

identification to assist in prediction of Induced Seismic events during well completions. Operationally, Canbriam has RTC or ‘request to complete’ meetings which include full integration of subsurface and operations. Decisions in these meetings are relayed to the field to ensure any potential risks such as inter-well communication, casing deformation and induced seismicity are well understood.

IntroductionCanbriam has been monitoring induced seismicity since early 2015 with a backbone array of seismometers. Additional accelerometers have been added to better monitor ground motion. The array is real-time capable with Mc <0.5 and <500m hypocentre accuracy. This array, together with some temporary dense arrays, have enabled Canbriam to optimize completions and mitigate induced seismicity in 58 wells, having only 3 hydraulic frac related events exceeding 2M

L since array inception in 2015.

ExamplesFive North Altares Montney completion case studies are presented in detail in the Joint-Convention talk. In this extended abstract, three case studies are discussed in less detail. These examples illustrate the application of the integrated subsurface work combined with seismic events from the monitoring array to make operational decisions while completing the horizontal wells. Figure 2 below illustrates the study areas A & B, in which pads have been completed demonstrating the often predictable nature of induced seismicity.

Area A

The first example is Area A highlighted on figure 3. This is an Upper Montney completion by another Operator, bounded

to the South by a large strike-slip fault. Canbriam added an extra seismometer to the backbone array in order to better locate any resulting induced seismicity events resulting from this pad.




Area A Results

Figure 3 illustrates the induced seismicity events associated with the completion operations by the Operator. It was apparent that in the last 1/3 (heel) of the well, seismicity events increased rapidly in terms of both number and magnitude approaching the strike-slip fault. Two large events occurred, 2.78M

L and 3.82M

L , close to the heel. Post

frack events occurred consistently for more than a month along the strike-slip fault. In addition, work was performed to evaluate the b-value associated with the microseismic events. The ‘b’ plot indicated a gradient <1, which is likely to be associated with ‘existing fault’ movement rather than ‘man-made’ activity.

Shake maps were also constructed, post job, to evaluate the ground motion associated with the largest (3.82 M

L ) event using an

Altares-specific ground motion prediction equation and site amplification map. The surface motion exceeded the BCOGC’s 2017 notification threshold of 2% peak ground acceleration. The b-plot and shake map are illustrated in figures 4 and 5 below.

Area B

Within area B, two Canbriam pads are discussed. Firstly, a pad drilled in 2015 from which there were several learnings and secondly, a pad completed in 2017 to which these learnings were applied. Figure 6 shows the two areas, wells and faults. The wells on both pads are similar in that they were drilled parallel to and >200m away from a large thrust fault to the East which runs perpendicular to maximum horizontal stress. In addition, there is an E-W strike-slip fault, forming 2 compartments in the area.

Area B 2015 Results

In the 2015 example, 4 wells were completed on the Pad; a Lower Montney first, followed by 3 Upper Montney wells. During the Lower Montney completion, two seismic events greater than M

L 2.0 were observed.

This triggered Canbriam’s 2015 internal traffic light protocol (TLP). Near-real time monitoring of events allowed both field and Calgary, when >2.0M

L events were recorded,

to immediately reduce treating rate and corresponding pressure on subsequent stages. Note that this TLP has now been modified to be more in line with BCOGC requirements for ground motion rather than magnitude and will be discussed later in the talk. No further events >2.0M

L were observed

for the remainder of the Lower Montney completions using the reduced treating rate and pressure. Next, 3 additional wells were completed in the Upper Montney at ‘normal’ treatment pressure with no events >1.0M

L.

This is consistent with the Canbriam model of the Lower Montney being more prone to seeing deeper pre-existing natural fractures which results in higher levels of induced seismicity. These larger fractures appear not to propagate higher in the section and tend to die out in the Upper Montney, probably as a result of differing mechanical properties and stresses between the two formations.

In 2017, a similar pad was completed, as shown in figure 6. Lower Montney first, followed by 3 Upper Montney wells.The wells were in a similar position to the previous pad in relation to the large thrust fault. Learnings from the 2015 work were incorporated into the completions planning in Calgary and the field operation. Notably, an expectation that completions in the Lower Montney may give rise to larger induced seismic events than the Upper Montney, being closer to the deep seated structures with their associated fractures.This and the proximity of the wells to the thrust fault were considered in the pre-job ‘request to complete’ (RTC), where detailed subsurface reservoir characterization is used to plan possible seismicity outcomes.


Area B 2017 Results

Figure 7 illustrates the same area in more detail. Note that accelerometers were added in 2016 and ground motion mapping (shake-maps) were available, rather than the purely magnitude based results of 2015. The toe 1/3 of the well was completed using sliding sleeves with no induced seismicity >1.0M

L. As the completions moved closer

to the smaller fault, shown with the dotted red line in figure 7, induced seismicity was anticipated as this is likely to be connected to the thrust fault. Without pre-cursor events, a magnitude 3.27M

L event was recorded

shown in yellow on the thrust fault in figure 7. Once again (first time since 2015), this triggered Canbriam’s traffic light protocol.The OGC were notified and pump rate, tonnage and max treating pressure were reduced. Following this, another 6 sleeves were completed at the lower rates and continued to see seismicity >2.0M

L. Several

sleeves that were closer to the fault were then skipped and 4 more sleeves were fracked.

During this time, two larger events were seen with magnitudes 2.78M

L and 3.33M

L

respectively. Both appeared to be on the thrust fault, shown on figure 7 with closely spaced green and yellow dots. At this point the frac job was shut down and moved to the first Upper Montney well. This was to allow the increased pressure due to the stimulation in the Lower Montney time to dissipate.

This Upper Montney well was completed in its entirety with no seismic events >1.0M

L.

The crew returned to the Lower Montney well and completed it with no events >1.0M

L.

Based on recorded surface pressure, the fracture network (natural and stimulated) had bled down to a level that reduced the intensity of subsequent events.

As with Area A, shake maps were produced in Area B for the larger induced seismicity events. The same Altares-specific ground motion prediction equation and site amplification map were used.

Figure 8 illustrates the shake map for the 3.33M

L event in 2017. This event lead to a

peak ground acceleration >2%g, which is higher than the OGC limit. This event was weakly felt on surface. These shake maps have allowed Canbriam to calibrate induced seismicity in Altares to understand what the ground motion will be corresponding to event magnitude, and thereby produce a more refined TLP. Specifically, by modelling ground motion threshold scenarios (based on BCOGC 0.8% peak ground acceleration), Canbriam is able to determine a more accurate corresponding magnitude value.

ConclusionsThe backbone seismometer and accelerometer array has allowed us to produce robust ‘shake maps’ based upon ground motion.

This in turn, has enabled us to define an Altares-specific ground motion traffic light protocol (TLP), using accelerometer data which is implemented before completions.This implementation will be shown at the convention presentation for the c-54-A pad hydraulic fracture operations.

The importance of good subsurface reservoir characterization and integration with the completions team before and during the frack jobs cannot be under-stated.

Lower Montney completions can be expected to generate higher magnitude induced seismicity events and should be handled accordingly in pre–completions planning.

The ability to picture the subsurface using the 3D seismic and induced seismicity events recorded from the backbone array

gives Canbriam a predictive capability for pre-drill and completions planning. In addition, an understanding of the size of and proximity to the larger faults in the area lead to the technique of pressure dissipation in the Lower Montney. So far, our predictive work has indicated “big faults” can have potentially “big Induced Seismicity events”

This extended abstract will be discussed in further detail during the joint Convention presentation by Brad Bialowas on May7th

AcknowledgementsThe authors wish to acknowledge Canbriam Energy for permission to show this work. In addition we would like to thank all the members of the Subsurface and Operations teams for their contribution to this work. Thanks to Seitel for permission to show 3D seismic derivatives. Thanks are due to Nanometrics for backbone array services and ground motion processing.

ReferencesBatlai, B. Martinez, H. Nieto, J. Janega, G. Using geoscience to optimize completions in the Montney formation, N.E British Columbia., Canbriam Energy Inc GeoConvention 2017

Yenier, E. Baturan, B. Bialowas, B. Batlai, B. Nieto, J. Induced seismicity risk mitigation strategies; A Montney case study., Nanometrics Inc and Canbriam Energy Inc

Nieto, J.A. Bercha , R.L. Chan, J The Montney and Muskwa formations are they Barnett shale look-alikes? The Society of Petrophysicists and Well log Analysts 50th Symposium. 2009




STRATIGRAPHIC PATTERNS OF ORGANIC CARBON ENRICHMENT IN THE UPPER DEVONIAN DUVERNAY FORMATION, ALBERTANicholas B. Harris1, Maria Mastalerz2, Julia M. McMillan1*, Levi J. Knapp1+ 1 University of Alberta, 2 Indiana Geological Survey, * Now at Imperial Oil Limited, + Now at Japan Oil, Gas and Metals National Corporation

Summary Organic carbon enrichment in Duvernay Formation mudstones is related to sequence stratigraphic systems tracts and to paleogeographic position with respect to the Rimbey-Meadowbrook Trend, a a major reef trend that separates the carbonate-rich East Shale Basin (ESB) from the siliceous West Shale Basin (WSB). In the WSB, above a second order maximum flooding surface, TOC peaks just above third order maximum flooding surfaces and decreases gradually through the highstand systems tracts. TOCs are generally lower below the second order maximum flooding surface and are highest in the third order transgressive systems tract. In the ESB, organic enrichment is less regular and apparently related to dilution by carbonate shed from adjacent platforms.

IntroductionThe accumulation of organic matter in mudstones has been related to sequence stratigraphy and transgressive – regressive cycles in numerous studies over the past 25 years. Such studies commonly predicate their interpretations on the assumption that organic matter is particularly enriched in transgressive systems tracts or at maximum flooding surfaces. This assumption is generally supported by careful sequence stratigraphic analyses of black shale systems (e.g. Arthur and Sageman, 2004). These interpretations implicitly (or explicitly) assume that increasing water depth leads to reduced oxygen levels, which enhances organic preservation, and to reduced sedimentation rates, which concentrates organic matter. Models for organic enrichment based on bioproductivity are less obviously related to transgressive systems tracts or maximum flooding surfaces. Some researchers note that the importance of feedback loops between

these factors that also do not necessarily lend themselves to a simple transgressive model.

We test the relationship between organic carbon accumulation and position within a stratigraphic sequence in the Duvernay Formation of the Western Canada Sedimentary Basin, developing a core-based sequence stratigraphic interpretation and comparing it to a high resolution geochemical and organic petrologic database. This data set enables us to associate total organic matter content and specific organic assemblages with particular systems tracts and to examine how the organic assemblages change across the basin. These are tested against proxies for redox conditions and bioproductivity to relate relative sea level to specific mechanisms for organic accumulation.

Dataset and MethodsThe sequence stratigraphic analysis of the Duvernay Formation is based on detailed core descriptions and interpretations of 8 cores from exploration wells located from the Peace River Arch in the north nearly to the Killiam Reef in the south and from the eastern margin of the basin to the deep basin near the deformation front. Studied wells represent both the East Shale Basin (ESB), southeast of the Rimbey-Meadowbrook Trend, and the West Shale Basin (WSB) to the northwest of the Trend. An additional 16 cores were examined more briefly to fill gaps in our core coverage. Facies and stratigraphic results are presented in Knapp (2016) and Knapp et al. (2017). Five wells, 3 from the

WSB and 2 from the ESB, were selected for geochemical analysis, including major, minor and trace element analysis by ICP and ICP-MS, total organic carbon (TOC) by LECO analysis and Rock-eval parameters by the Weatherford Source Rock Analyzer. Core were sampled at a spacing of 1 meter or finer, and organic and inorganic geochemical analyses represent identical splits of each sample. Geochemical analytic procedures and results are reported in McMillan (2016). Three wells with a total of 38 samples were selected for

Figure 1. Map of the Alberta portion of the Western Canada Basin, showing basin paleogeography in the early Frasnian. Locations of wells with geochemical data are shown.




organic petrologic analysis. Samples were prepared as polished blocks following the standard organic petrography techniques. Vitrinite and solid bitumen reflectance was measured with a Zeiss Photoscope. Maceral analysis was conducted by point-counting 500 spots on each sample, and recalculated to volume %.

ResultsThe Duvernay Formation comprises three third order sequences, termed DS1, DS2 and DS3 in ascending order (Knapp, 2016). These are superimposed on a second order late transgressive systems tract and early highstand systems tract, where the second order maximum flooding surface coincides with the maximum flooding surface of DS2. DS1 corresponds to the lower Duvernay, with the middle Duvernay carbonate unit marking the maximum regressive surface at the top of the DS1. DS2 and DS3 together correspond to the upper Duvernay. The sequences are composed almost entirely of transgressive systems tracts (TSTs) and highstand systems tracts (HSTs). A lowstand systems tract (LST) is only

present at the base of DS3, which effectively marks the second order sea level turnaround. Depositional facies generally vary from bioturbated carbonate-rich siltstones to siliceous mudstones from the platform margins to basin center (Knapp et al., 2017); sections from the ESB are generally carbonate-rich whereas sections from the WSB are siliceous.

Duvernay shales represent a range of organic enrichment and organic matter type. Organic petrologic analysis records predominantly amorphous organic matter and solid bitumen, with much less abundant vitrinite and inertinite. Organic matter type indicated by Rock-eval analysis shows that in most cases, lower TOC content is associated with poorer quality organic matter (low hydrogen index), indicating

either more reducing conditions or higher bioproductivity were responsibility for organic enrichment. However, in a carbonate-rich part of the East Shale Basin, hydrogen index is uncorrelated with TOC, indicating that here, dilution by carbonate minerals was the primary control on organic enrichment.

Stratigraphic patterns of organic carbon enrichment in the WSB are consistent. Highest TOCs are recorded just above the maximum flooding surface in DS2 (also the second order MFS). Secondary peaks in TOC are recorded above the MFS in DS3 and in the transgressive systems tract of DS1. Low TOC values are recorded in the lowstand systems tract of DS3 and in the transgressive systems tracts of DS2 and DS3 almost up to the MFSs. Organic carbon concentrations are related to proxies for redox conditions and bioproductivity. Organic enrichment in the central ESB is erratic, varying sharply over narrow stratigraphic intervals, probably reflecting variable sedimentation rates.

ConclusionsOrganic enrichment in the Duvernay Formation is predictable in a sequence stratigraphic framework throughout much of the Alberta portion of the Western Canada Sedimentary Basin. Above a second order maximum flooding surface, TOC is highest just above third order maximum flooding surfaces. TOCs are lower below the second order maximum flooding surface and are most enriched in the transgressive systems tract.

AcknowledgementsFunding was provided by a grant from NSERC (CRDPJ 445064–12) and cofunders ConocoPhillips Canada, Devon Canada, Husky Energy, Imperial, Nexen-CNOOC, and Shell Canada. We are grateful for their support.

ReferencesArthur, M.A., and Sageman, B.B., 2005, Sea-level control on source-rock development: Perspectives from the Holocene Black Sea, the mid-Cretaceous Western Interior Basin of North America, and the Late Devonian Appalachian Basin, in Harris, N.B., ed., The Deposition of Organic-Carbon-Rich Sediments: Models, Mechanisms, and Consequences: Society for Sedimentary Geology (SEPM) Special Publication 82, p. 35–59, https://doi.org /10.2110 /pec.05.82.0035.

Knapp, L.J., 2016. Controls on Organic-Rich Mudstone Deposition: The Devonian Duvernay Formation, Alberta, Canada. (M.Sc. thesis). University of Alberta, Edmonton, Canada.

Knapp, L.J., McMillan, J.M., Harris, N.B., 2017. A depositional model for organic-rich Duvernay Formation mudstones. Sedimentary Geology 347, 160-182.

McMillan, J.M., 2016. Expression of major and trace element signatures of the Frasnian Duvernay Formation within a sea level context: insights into the process that control mudstone composition, paleoredox conditions and organic matter enrichment. M.Sc. thesis, University of Alberta, Canada, 445p.

Figure 2. Facies and sequence stratigraphic interpretation of the Encana Cecilia 100-02-22-63-20W5 well. TOC data are shown in relationship to stratigraphic sequences.




DON’T CALL IT A COMEBACK – DELIVERING THE GOODS IN THE ALIDA UNIT, SE SASKATCHEWANJason E. Shtand, NAL Resources Ltd.

SummaryThe Alida unit of SE Saskatchewan, first discovered in 1954, is a mature, low-decline oil and gas field still producing today conventionally from the Alida Beds (Mississippian). The Alida pool is a stratigraphic pinch out with an OOIP of 75MM bbl and OGIP of 70 BCF with a present-day recovery factor of 41%. The reservoir is composed of a thick 5 to 40m carbonate unit, characterized by a typically skeletal, crinoidal, limestone packstone or grainstone which has undergone varying degrees of dolomitization.

Despite the gas cap blow down beginning in 1967, bottom-hole pressures remain near virgin due to the presence of a strong bottom-drive aquifer. While this aquifer provides pressure support to producing wells, it has led to an elevated and irregular oil water contact as water moved in to replace the void space of produced oil and gas. It is also believed that there is water coning to vertical perforations and open-hole horizontals,

which can lead to increased water cuts at the well head, while leaving behind un-swept oil between existing producers.

After the initial vertical development of 59 wells, the pool now contains 114 horizontal wells producing at 75 to 150m spacing, from various structural elevations within the Alida Beds. Horizontal well results have been extremely successful, producing an additional 15.9MM bbl of oil to date, nearly doubling the unit’s overall recovery factory. The horizontal well results by vintage have shown progressively worse individual initial production rates and ultimate recoveries over time from 2000 to 2012. Renewed stratigraphic correlations and mapping using 3D seismic and reservoir evaluation has helped target the remaining areas of high oil saturation with a systematic approach. This led to the very successful results and strong economics for NAL’s 2017 infill drilling program, seeing production rates and expected ultimate recoveries return to that of the wells drilled during 2005-2009.

Geologic Setting and Pool Reservoir ParametersThe Alida unit (Fig. 1) located at TWP 5-6 RNG 33W1 is one of many pools producing from a pronounced carbonate structural nose within the Alida Beds against the Mississippian unconformity subcrop in SE Saskatchewan. Erosion at this surface cuts down into the sequence package and has led to a wedging out of the Alida Beds towards the up-dip, northeastern edge, as well as down the structural flanks of the reservoir (Fig. 2 and 3). The carbonate stack is capped by a diagenetic anhydrite and dense dolomite of variable thickness, above which the post-Mississippian impermeable lower Watrous beds were deposited. This impermeable cap and overlay combined with the structural closure create the trapping mechanism for the pool.

Deposition of the Alida occurred on a broad carbonate shelf within shallow-marine waters during an overall shallowing upward trend. (Kent, 1984.) Regionally, six main

Figure 1. The Alida Unit is located at TWP 5-6 RNG 33W1 in SE Saskatchewan. The pool was originally developed vertically, and wells were typically cored. Unitization occurred in 1957. A – A’ cross-section is illustrated in Figure 2.

Figure 2. Schematic cross-section of the Alida Unit across A – A’ from Figure 1, showing Mississippian unconformity, dipping carbonate beds, and the original oil-water and oil-gas contacts.




lithofacies have been described within the Alida Beds (Rott, 2005.) While the Alida unit reservoir is a carbonate package with a complex history of diagenesis, for the purposes of this presentation, the reservoir has been divided into two main lithofacies. An upper crinoid unit consisting of a typically limestone packstone or grainstone and a lower algal unit, consisting of partially dolomitic limestone. Other units of importance are smaller argillaceous marker beds that represent transgressive incursions. The units have slightly elevated gamma ray values and a SP shift, making them good local correlation markers.

Average limestone porosity within the unit is 16%, typically intercrystalline and interparticle with minor vuggy and dissolution porosity. Maximum permeabilities average 30mD, with kvert to k90 ratios of 0.3 – 0.5. This good vertical permeability combined with vertical fractures (as seen in core), leads to the belief

that the reservoir is acting locally as a tank.

The Alida Beds within the unit dip to the southwest, toward the center of the Williston Basin, at a present day depth of 1100 – 1140m TVD (-510 to -550m SS). At time of discovery, the reservoir was normally pressured at 10,500 kPa, and over the course of 60 years of production, pool pressures have only declined ~12%, despite gas cap blow down and low voidage replacement through water injection into the Alida. This is due to strong bottom-drive aquifer support as evidenced in production profiles showing increasing water cuts over time with relatively flat overall fluid production. While maintaining pressures, the aquifer support has led to substantial movement of fluid within the reservoir, including elevated oil-water contacts and oil migration into the original gas cap.

ApproachFrom 1990 to present, horizontal wells have been used to infill the Alida pool, contributing substantial new reserves without causing any major interference to existing producers (Vigrass, 1995). Older wells in the pool eventually develop water breakthrough due to coning, and considerable oil is left un-swept between producers. (Beveridge, 1991). After over two decades of drilling, horizontal type curves had reduced initial production rates and ultimate recoveries, challenging the economics of future drilling activity.

NAL’s appraoach to high grading better drilling locations was to use integrated detailed mapping, tying logs, core, seismic, and engineering data together to identify high remaining oil in place on a LSD scale. Estimated ultimate recovery factor for the unit is currently 46.5%. Locations that meet the criteria of having 75m interwell spacing, lateral lengths over 600m, and target areas of currently less than 40% recovery factor, are ideal for capturing higher reserves and delivering better economic results.

ExamplesAfter a four-year hiatus from drilling, five new 75m infill horizontal wells were drilled within the Alida unit during 2017. These wells had an average lateral length of 930 m, for drilling and open-hole completion costs of $0.7MM, and estimated rates of return on investment over 500% .

Combined, the wells brought on 739 bbl/d of flush oil and reached average peak initial production rates of 148 bbl/d of oil per well. Water cuts averaged 32.6%, producing directly in between older horizontals with current water cuts typically higher than 95%. Preliminary decline analysis suggests ultimate recoveries to be 100M bbl of oil per well. These results were last seen during drilling programs completed from 2005 to 2009 (Fig. 4). Additional locations have been identified for exploitation through future drilling programs. Complete development could deliver an additional risked 2.3MM bbl of oil, contributing a further 3% ultimate recovery factor for the unit.

ConclusionsWhen further developing mature pools, detailed geologic work integrated into a multi-disciplinary understanding of the reservoir is crucial for determining areas of high remaining oil saturation. Strategic horizontal drilling locations specifically targeting these areas can capture under-exploited reserves and deliver highly economic results.

ReferencesKent D.M. 1984. Carbonate and Associated Rocks of the Williston Basin: Their Origin, Diagenesis, and Economic Potential; Rocky Mountain Section, SEPM Short Course Notes, p137.

C.M. Rott and H. Qing. 2005. Sedimentology and Facies Description of Mississippian Alida Beds, Williston Basin, Southeastern Saskatchewan. Summary of Investigations 2005, Volume 1, Saskatchewan Geological Survey, Sask. Industry Resources, Misc. Rep. 2005-4.1, CD-ROM, Paper A-12, p10.

Arthur and Cisyk Geoconsulting and Development Ltd. A Geological Study of the Alida East MC-3 Beds of Southeastern Saskatchewan, Report prepared for NAL Resources.

L.W. Vigrass and R.G. Vigrass.1996. Horizontal Wells in the Rosebank Alida Beds Pool, Saskatchewan. The Journal of Canadian Petroleum Technology, Volume 35, No 3.

Beveridge Engineering Ltd. 1991. Performance Review Alida Unit No.1. Report prepare for NAL Resources.

Figure 3. Seismic time structure cube with amplitude overlay. 3D visual clearly showing the Mississippian unconformity surface and resulting remnant high.

Figure 4. Time-normalized average daily oil, grouped by horizontal drilling program vintage. 2017 drilling results saw a return to rates last obtained from 2005-2009.




BUILDING THE 3D PROVINCIAL GEOLOGICAL FRAMEWORK MODEL OF ALBERTA: INTEGRATING DECADES OF GEOLOGICAL INTERPRETATION AND OVER HALF A BILLION DATA POINTS TO CREATE A PROVINCIAL-SCALE GEOMODEL OF ALBERTA’S SUBSURFACE Paulina, Branscombe. Kelsey, MacCormack. Hilary, Corlett. Ben, Hathway. Tyler, Hauck. Jesse, Peterson. Mahshid, Babakhani.

Alberta Energy Regulator (Alberta Geological Survey)

SummaryThe Alberta Geological Survey (AGS) has created a foundational three-dimensional (3D) Provincial Geological Framework Model of Alberta V.1 (3D Model).

Introduction The 3D Model represents a multi-layer, stratigraphically related, holistic view of our geological understanding of select provincial-scale intervals within Alberta’s subsurface. This model covers 602,825 km2 of Alberta (excluding the area of Cordilleran deformation) and contains 32 layers extending from ground surface to an assigned flat base within the Precambrian at 5000m below sea level (Figure 1 and 2).

Theory and/or Method An iterative modelling approach, guided by conceptual models reflecting our collective geological understanding within the Western Canada Sedimentary Basin, was used to create a reasonable regional-scale characterization of the complex geology of Alberta. The input data was largely geophysical log-based stratigraphic picks interpreted by AGS/AER geologists (representing 618 998 of 620 812 data points) but also includes outcrop data and information from reports, maps and the Table of Formations (Alberta Geological Survey, 2015).

Traditional 2D mapping doesn’t allow us

to effectively characterize the integrated nature of the subsurface and its resources within our basin in a holistic way. This provincial-scale 3D model brings together decades of high quality but largely singular geological interpretations and 2D mapping into a 3D, multi-layer, stratigraphically related configuration.

Conclusions The AGS’ Geological Framework project has been designed using an evergreen modelling approach. It can be used for basin-scale geological investigations within the Alberta portion of the Western Canada Sedimentary Basin, and can

Figure 1. Oblique view (looking northwest) of all zones below the bedrock topography surface to the base of the model with the 3D Provincial Geological Framework Model of Alberta V.1 (Branscombe et al., in progress) (vertical exaggeration = 50x).




absorb new geological interpretation by the AGS and sub-models that the AGS Geological Modelling Team is developing for local-scale investigations. The 3D Provincial Geological Framework Model of Alberta is being used to support science based decision making at the AER and acts as the geological foundation to

inform regulatory decisions related to the management of the subsurface. This work not only enables AGS to deliver geoscience information to a variety of stakeholders in a new and visually stunning way, but more importantly allows us to deliver information in a useful and easy to understand format.

Acknowledgements

References Alberta Geological Survey (2015): Alberta Table of Formations; Alberta Energy Regulator, URL <http://ags.aer.ca/document/Table-of-Formations.pdf> [2017].

Branscombe, P., MacCormack, K.E., Babakhani, M. (in progress): 3D Provincial Geological Framework Model of Alberta V.1 – Methodology; Alberta Energy Regulator, AER/AGS.

Branscombe, P., MacCormack, K.E., Corlett, H.J., Hathway, B., Hauck, T.E., Peterson, J.T. (in progress): 3D Provincial Geological Framework Model of Alberta V.1 (dataset, multiple files); Alberta Energy Regulator, AER/AGS.

Figure 2. Oblique stacked (left) and exploded view (right) of all zones within the 3D Provincial Geological Framework Model of Alberta V.1 (vertical exaggeration = 60x) (Branscombe et al., in progress).




CORE CONFERENCE SESSION HIGHLIGHTS

GETTING BACK TO ROCKS 101 by Adam Fraser and Christa Williams

As our pools and fields are further exploited and unconventional reservoirs continue to increase in importance to our industry, the geoscience community needs to continually push the boundaries of our analysis and interpretation. Only when geoscientists can tie the data back to the rocks and refresh current understandings do we succeed in locating new opportunities, or develop new approaches to existing plays. From re-examining core analysis to performing geomechanical testing, core has been an integral part in breathing new life into old pools and understanding how we can exploit new ones.

At this year’s CSPG Core Conference on May 10th and 11th, there will be over 20 cores presented from across Canada, as well as some international core. These cores will cover a wide range of geologic topics: carbonate, conventional, unconventional, oil sands, and tight reservoirs will all be on display at the AER Core Research Centre over the 2-day event.

CarbonatesPresentations relating to Carbonates will show paleoenvironment and deposition, dolomitization, and porosity evaluation. Delegates will be able to see the progression of work from examples within the Williston basin and the Charlie Lake Formation.

Heavy Oil/Oil SandsDelegates will see examples of heavy oil and oil sands from the upper Mannville Group and the McMurray Formation. The core presented will show different aspects in understanding these types of plays, from regional tectonic controls on deposition, reservoir and hydrocarbon distribution, high order sequence stratigraphy, as well as caprock integrity.

Tight/ConventionalWithin the tight and conventional presentations, we will see examples of Cardium reservoir characterization and distribution from classic fields around Alberta. The Falher and Viking Formations will highlight examples of accommodation

space and facies variations. New this year, high resolution photos will be presented to show the sedimentology from Eastern Canada’s Scotian Shelf, and further afield, Kesan Formation core in the Thrace basin of Turkey will be displayed.

UnconventionalExamples of hydrocarbon potential in the Montney, Duvernay and the Horn River group will be on display with presentations to show the use different techniques used to understand various rock and geomechanical properties.

This year’s CSPG Core Conference will not be one to miss. With core examples from various play types throughout our country, as well as an international presence, it is sure to be an excellent 2-day event. The presentations will highlight challenges in interpretation, sequence stratigraphy, the “produce-ability” of our rocks, and ultimately tying that to reservoir quality. Delegates are sure to come away from the conference with a different view or new idea on how to approach a problem in their day-to-day work.

Of course there will be the yearly networking event of the Core Meltdown, held on Thursday at MacEwan Hall at the University of Calgary right after the final core presentation.

We look forward to seeing you there!


EAST SHALE DUVERNAY – WHAT’S THE APPEAL?Carolyn Currie, Integrated Reservoir Solutions, Core Laboratories

It’s still relatively early days for the East Shale Duvernay play, but has gained considerable momentum in the past

year. With land sale bids going through the roof earlier in 2017 (up to $5000/ha), this emerging light oil play is receiving lots of attention. Surprisingly, this is not the work of larger operators, but private companies and juniors are the one’s making inroads at developing this previously undeveloped region. So what makes this side of the Duvernay Basin so attractive?

The East Shale basin has three major things going for it including:

• Shallower than West Shale Basin Duvernay (av. 2000-2500 meters), meaning much cheaper drilling costs.

• Less mature than West Shale Basin Duvernay. The East Shale Basin Duvernay is entirely in the oil window, meaning more wells per section and higher valuations.

• The East Shale Basin Duvernay has a strong geographical advantage.

The area is well connected to infrastructure (i.e. pipelines, roads, etc) making accessibility easy and development costs much more manageable.

The Integrated Reservoir Solutions Division of Core Laboratories has conducted an industry sponsored project in the Duvernay, the majority of the wells being from the West Shale Basin Duvernay, however, have had a few cores derived in the East Shale Basin.

This presentation will highlight one of those cores from the Ghost Pine field as we look at the East Shale Basin Duvernay from the rock – up, including:

• Physical appearance (Figure 1)• Petrography/Mineralogy• Rock Properties o Porosity and Permeability o Saturations• Geochemistry o TOC

o Maturity• Geomechanics

This presentation will hopefully give all an appreciation of the complexity in the East Shale Basin, as it is very different than its ‘sister’ to the west.

Figure 1: Example of a typical East Shale Basin Duvernay core (CALTEX_RES HZ 102 GPINE 1-14-33-23W4). Highly interbedded carbonate and shale packages characterize the section. Shale beds are concentrated with organics, leading to higher than normal TOC content. Maturity analyses (i.e. vitrinite reflectance and Tmax) put this core in the oil window.

CORE CONFERENCE TECHNICAL ABSTRACTS


DOLOMITIZATION AND POROSITY EVOLUTION – PETROGRAPHIC DIAGENESIS OF THE CHARLIE LAKE FORMATION, AN EMERGING TIGHT OIL GIANTCathy M. Hamel, CMH Petrology Consultant Inc & Tim Geldreich, Longshore Resources

The Charlie Lake Formation contains stacked light oil intervals and has been recognized as a significant

hydrocarbon resource covering a large area in Alberta and British Columbia. Vertical well results combined with geological evaluation of core and thin sections has improved the resolution and size of the resource in place. Longshore Resources, among others, has successfully applied horizontal drilling technology in the Charlie Lake Formation located in the Peace River Embayment of west central Alberta. The exploitation of the Charlie Lake play relies on the delineation of the net reservoir thickness distributions in combination with mineralogy and depositional texture associations. Thin section analysis of the carbonate and mixed siliciclastic sequence, above and below the regionally recognized angular Coplin Unconformity, reveals the importance of understanding the diagenetic sequence that these sediments have undergone. Overall, the cyclic vertical facies stacking of the carbonates and mixed siliciclastic is consistent with a relatively low depositional energy environment consisting of mostly skeletal muds which have been exposed to evaporitic fluids. The interpreted carbonate paragenetic sequence is relatively straightforward, with most of the diagenetic processes occurring within the environment of deposition or during shallow burial. The dolomitization processes of effective pore system development in the evaporite related Charlie Lake sediments, can directly be related to permeability, reservoir quality and economic feasibility of the once deemed bypass pay target zones. Specific examples of porosity evolution within the carbonate and siliciclastic succession will be presented in order to understand the fast emerging Charlie Lake Formation tight oil giant.



RESERVOIR FACIES OF THE KESAN FORMATION: TIGHT GAS EXPLORATION IN THE THRACE BASIN OF N.W. TURKEYThomas F. Moslow, Moslow Geoscience Consulting, Calgary, Alberta

Richard H.T Callow, Statoil ASA, Stavanger, Norway

Rob Sadownyk, Valeura Energy Inc. Calgary, Alberta

Antoine Riault, Statoil ASA, Oslo, Norway

The Yamalik-1 well was drilled in 2017 to test the concept of a basin-centered gas accumulation in

the Thrace Basin, N.W. Turkey. Three conventional cores from different reservoir levels and stratigraphic intervals provide an excellent example of a broad spectrum of fine-grained turbidite facies that have been flow tested with preliminary successful results. Core #3 from the Eocene-age Kesan Formation is selected for display as a good representation of a reservoir target in the basin. Fifty-two and a half metres of whole diameter core is displayed and described with respect to sedimentary structures, lithology, texture, fractures, diagenetic

features and composition (Fig. 1). An extensive core sampling program provides additional data including biostratigraphic age, micropaleontological assemblages, porosity, permeability and XRD.

An interpreted depositional environment is provided for all facies, which was based on the combination of physical and biogenic sedimentary structures, and the interpreted physical depositional processes. A summary of the facies associations and their sedimentary characteristics, inferred processes of deposition and relevant diagenetic features has also been compiled. Sedimentary cycles and significant

bounding surfaces were identified in the core and have been correlated to core-gamma ray and downhole wireline logs including over 1700m of FMI log data (Fig. 2).

Most of the sandstone facies in the Kesan Formation are interpreted as the product of sediment gravity flow processes that were sourced from a deltaic complex to the south. Approximately 85% of the sandstone facies observed in the core occur as either thin-or thick-bedded turbidites that are interpreted as the proximal to distal deposits of the various elements of submarine fan channel and/or lobe environments

Fig. 1. Composite graphic log of the Kesan Fm. in Core #3 of the Yamalik-1 well summarizing sedimentologic observations. Lithofacies are color coded as follows: yellow is vf-f sandstone; orange is sandy coarse siltstone; brown is variably carbonaceous mudstone.

Fig. 2: Yamalik-1 Core #3 calibrated to downhole gamma log showing perforated intervals. Red arrows show interpreted cycles of upwards increasing and decreasing gamma ray values which correspond to thickening and thinning cycles observed in the core.



(Fig. 2). Potentially channelized and the most proximal lobe deposits consist of very fine- to medium-grained sandstones that can in some cases contain numerous mudstone intraclasts. These deposits are organised into

thickly bedded, normally graded, commonly amalgamated Ta, Ta-b and Ta-b-c turbidite beds that may reflect deposition from high density turbidity currents. Beds are commonly massive in appearance but sedimentary structures include planar and ripple cross-lamination, contorted to convoluted laminae, dish structures, and large-scale flame structures. The thickest example of the axial submarine channel and lobe facies association occurs in the upper one-third of the Kesan core from 3427 – 3435m where the highest porosity measurements are observed from core analysis (Fig. 1). This interval fines upwards from medium to very fine-grained sandstone, and bed thickness and net to gross ratio decreases upwards.

Marginal or weakly channelized facies

consist of medium bedded (cm-dm scale) heterolithic, interbedded silty very fine-grained sandstone and sandy coarse siltstone to mudstone. Sandstones with high clay contents are also observed commonly in this facies association. Dewatering structures occur commonly in the form of small sand injectites, dishes and flame structures. Another common attribute of this facies association is the occurrence of relatively thin beds characterized by parallel or ripple cross lamination, including aggradational climbing ripples that display carbonaceous debris as resedimented plant detritus on foreset laminae. Inferred processes include deposition from sediment gravity flows (mostly low-density turbidity currents) and suspension deposition.

The majority of turbidite beds observed in the core are thin bedded (mm-cm scale) sandstones with ripple cross lamination, parallel lamination and starved ripples, that are interbedded with fine-grained siltstone to mudstone deposits. This facies is interpreted as distal channel overbank

and/or distal lobe deposits of low density turbidity currents. Internally deformed or contorted beds are interpreted as soft-sediment deformation and possible mass-wasting due to subaqueous slumps.

Regional 2D seismic lines have been used to constrain the depositional environment of the cored section, which would be challenging in the absence of a good regional context. It is possible to link the Kesan Formation strata in the Yamalik-1 well to a set of prograding clinoforms sourced from the basin margin several tens of kilometres to the south. Continued progradation in the overlying section indicates that at least some of the younger interval may represent more proximal slope or prodeltaic deposits. These observations are also consistent with those of abundant, terrestrially derived, resedimented plant detritus in the core, geochemical signatures from kerogen typing and a strong terrestrial signature recorded in some of the palynological assemblages.

Technical Program and Abstracts are now posted! Visit cspg.org/gussow today

REGISTRATION NOW OPEN



Thank you to our sponsors!

On-site Registration still available!

General Delegate Registration: $190.00 *Core Meltdown ticket included Thursday Day Rate $110.00 *Core Meltdown ticket NOT included Friday Day Rate $110.00 *Core Meltdown ticket NOT included

At this year’s CSPG Core Conference on May 10th and 11th, there will be over 20 cores presented from across Canada, as well as some international core. These cores will cover a wide range of

geologic topics: carbonate, conventional, unconventional, oil sands, and tight reservoirs will all be on display at the AER Core Research Centre over the 2-day event.

The AGAT Core Meltdown has

moved to Thursday


INSPIRING ENERGY INNOVATION THROUGH THE ALBERTA ENERGY REGULATOR’S CORE RESEARCH CENTREWhile people may think of a facility that boasts a collection of some two million metres of core and 20 million vials of drill cuttings as nothing more than a storage site, its employees and visitors might beg to differ.

Located near the University of Calgary, the Alberta Energy Regulator’s (AER) 200,000-square-foot Core Research Centre (CRC) holds one of the largest, most complete drilling histories in the world.

“Access to the physical data at the CRC is a significant, competitive advantage for companies wanting to explore for hydrocarbons in Alberta,” explains the CRC’s director, Ray Kuntz. “Investors and geoscientists have immediate and affordable access to geological data, which means they can test their hypotheses without actually having to drill themselves.”

Kuntz is quick to point out another advantage of the CRC that isn’t immediately obvious: the collaboration that happens among patrons, often over coffee in the lounge. This collaborative atmosphere is only magnified during the Canadian Society of Petroleum Geologists (CSPG) Core Conference.

The CRC’s sponsorship of the Core Conference – which it has hosted the core viewing portion for over 40 years – means that one of Canada’s largest gatherings of geoscientists assembles inside the CRC for that very purpose. Industry professionals are able to share ideas on a myriad of core and geologic topics, including carbon sequestration, CO

2, and geothermal energy

with decades of physical, historical data at their disposal.

This lends itself to the AER’s mandate of ensuring the safe, efficient, orderly, and environmentally responsible development of the province’s hydrocarbons. Alberta’s energy sector is vast and complex, and requires a regulator that is knowledgeable and equipped to manage large, established

reserves, which include:

• 1.6 billion barrels of conventional oil• 165 billion barrels of bitumen• 28.2 trillion cubic feet of natural gas• 36.6 billion tons of coal

“In my opinion, one of the things that Alberta is most known for is the innovative and creative mindset of the people who work in this industry,” Kuntz says. “Core and cuttings are the most basic source of truth documents we have for exploring and finding new hydrocarbons. This kind of information being so accessible, not just to us but to people from around the world, helps to foster this type of attitude.”

In the same way, Kuntz acknowledges that while the facility appeals to other jurisdictions, the AER gains a lot from having so many international clients walk through its doors. In 2017 alone, the CRC saw close to 300 people from over 20 countries pass through its facility.

Through sponsorship of the Core Conference, the AER is able to invest in Alberta’s energy future by collaborating with world partners and promoting good business practices within its own borders.

About the AERThe Government of Alberta created the AER in 2013 when it proclaimed the Responsible Energy Development Act. The regulator, under authority of the provincial government, took on regulatory functions related to energy development, which were previously held by Alberta Environment and Parks (previously Alberta Environment and Sustainable Resource Development), and combined them with the regulatory functions of the AER’s predecessor, the Energy Resources Conservation Board.

The AER employs around 1,200 staff, including inspectors, technical staff, engineers, geologists, scientists, investigators, stakeholder engagement specialists, mediators, lawyers, regulatory

experts, and other employees in 15 offices and field centres around Alberta.

SPONSOR SPOTLIGHT


WEATHERFORD

Weatherford and its predecessor Hycal Energy Research Laboratories Ltd. (Hycal) have

been proud to sponsor the core conference for well over a decade. A lot has changed over those years. We’ve seen companies, plays, methods, and people come and go but one thing that hasn’t changed is the excitement and positivity shown by geoscientists each Spring during the conference. We look forward to seeing and feeding all of you May 10th and 11th.

The spring season is always full of optimism and fortunately, even during difficult times, so is this oil and gas industry. The theme for this year’s conference is “Back to Basics” which goes well with Weatherford Labs’ moto of core and fluids as the “ground truth”. We are seeing clients go back to basics and question previous beliefs while at the same time pursuing new and exciting ideas such as lean gas cycling in order to deliver much needed value to the bottom line.

Weatherford Labs is pleased to be at the forefront of the Lean Gas Cycling movement here in Calgary. Dr. Brent Thomas, a Hycal principal, has designed a protocol and is overseeing each project which will expose the fundamental mechanisms involved in increasing liquid production in unconventional reservoirs for maximum positive financial impact. This project incorporates several labs services but in the end still relies on core and fluids as the “ground truth”.

Weatherford Labs splits our service offerings into 4 general areas:

1. Wellsite Services“Good data starts at the wellsite” and Weatherford’s Wellsite Services group has highly qualified and experienced field operators to provide our clients with confidence that their future data is safe. Any successful reservoir fluid or core analysis campaign hinges on the ability to collect sufficient volumes of high quality, representative reservoir material. Whether it is to safely retrieve and preserve core or to capture high quality PVT samples for analysis, Weatherford’s wellsite protocols have the highest standards in the industry with the unrelenting focus on safety and quality that our clients deserve.

2. Routine Core Analysis (RCA)Routine Core Analysis is a term that covers a long list of services, and with a customized approach to each formation and problem, these services are often anything but routine. Our petrophysical core analysis services include routine core analysis, crushed rock analysis, mercury injection capillary pressure, electrical properties, and nuclear magnetic resonance. With ever-growing experience in the area of tight rock, Weatherford is at the forefront of understanding the limitations of these tests and applying modifications to overcome them. In addition, Weatherford has extensive capabilities and expertise in the areas of geochemistry, petrophysics, and

rock mechanics.

3. Special Core Analysis (SCAL)Weatherford Laboratories has over 35 years of experience conducting Special Core Analysis including studies on all formations in Western Canada as well as many reservoirs overseas. Each reservoir is unique and our strength is in our ability to provide custom solutions to our clients’ reservoir problems while being able to closely replicate reservoir conditions. Actual reservoir fluids and core samples are used at reservoir temperatures and pressures to provide real solutions without the need for unnecessary modeling or assumptions.

4. Reservoir Fluid Analysis Weatherford’s 4 decades of innovation with Reservoir Fluid Analysis is the perfect complement for our core analysis expertise. Our H

2S certified laboratory in Calgary is

equipped with a vast selection of versatile instruments that allow us to develop unique customizable solutions for clients here in Canada and around the world. The list of fluid services is too extensive to list but it is safe to say if our clients have questions regarding their fluids in production or interaction downhole, we have the experience, equipment, and ability to find the answers they need.

We hope to see you on March 10th and 11th. Lunch is on us!

SPONSOR SPOTLIGHT

DIVISION TALKS


HEAVY OIL / OIL SANDS TECHNICAL DIVISION TALK

From Wellsite to Report, Key Aspects of a CAPROCK Core Workflow SPEAKERJason Tucker, Team Lead, Rock Mechanics Group, AGAT Laboratories Inc.

Time: 8:00 am Date: Wednesday, May 2, 2018 Location: Halliburton Training Centre, Room 1830, 645 – 7th Ave, SW, Calgary AB

ABSTRACTSampling for mechanical testing requires intact, well preserved and competent core intervals with a minimum amount of disturbance. Fragile and poorly consolidated zones have always been difficult to sample, particularly after core has been allowed to desiccate for extended periods of time. Field collection, core transport and handling, core storage and sample selection are all key factors in collecting samples that are representative and meaningful for geomechanics testing, AGAT Laboratories has established a rigorous workflow which incorporates all aspects of field handling, sample selection and testing. This presentation

provides an overview of best practice inputs when planning and implementing a geomechanical program.

The talk focuses on each stage of a geomechanics program and the critical considerations aimed at increasing the success rate of capturing and analyzing core samples. During the early stages of capturing a core for testing, core desiccation and transport are two of the key factors in preserving the quality of a core. Minimizing mechanical agitation and desiccation decreases the potential for breakage along bedding parallel partings. Particularly with poorly consolidated cores, sample selection is often limited due to the fragile nature of the core. CT scanning provides an optimal means to view the core in 3D to assess zones of low integrity, extensive fracturing or poor consolidation. Based on density variability, CT imaging allows the operator to identify different compositional zones within the core and evaluate the number of samples required to properly assess the mechanical properties. When sample have been collected, the final stage of testing begins. AGAT Laboratories has a state of the art

facility in Calgary with testing capabilities designed to evaluate rocks at ambient conditions and reservoir temperature and pressure conditions. AGAT Laboratories has extensive experience and the ability to pre-plan and execute an optimized testing program allowing for a seamless workflow from wellsite to final product.

BIOGRAPHYJason Tucker is currently the Team Lead of the rock mechanic division at AGAT Laboratories (recently purchased from Trican Well Service). Jason works on a broad range of projects from heavy oil caprock to unconventional shale plays. Jason graduated from the University of Calgary in 2012 with a Bachelor of Science in geophysics.

DIVISION INFORMATIONPlease confirm your attendance in advance by emailing [email protected]

NOTE: most Division events have a waiting list.

DIVISION TALKS


INTERNATIONAL TECHNICAL DIVISION TALK

Petroleum Geology of the Levant Basin, Southeast Mediterranean Sea: A Successful Exploration HistorySPEAKERCraig Boland M. Sc., P. Geol. Boland Exploration Consulting

Time: 12:00 pm Date: Wednesday, May 16, 2018Location: CNOOC Nexen Annex Theatre, 801-7th Ave SW, Calgary ABSTRACTThe Levant (Levantine) Basin is considered by many petroleum geologists as one of the world’s most promising and under explored petroleum regions.

The Basin development is related to the thermal subsidence and subduction of the Neo-Tethys Ocean under the Cyprus margin to the north of the basin during the collision of the Eurasian, African and Arabian tectonic plates at the end of the Cretaceous Period. The result is a closed ocean with a series of massive channelized systems originating from the proto-Nile drainage system depositing fan delta siliciclastics northwards over an extensive carbonate platform into the deep basin.

The rifting of the Gulf of Suez and the Red Sea break-up throughout the Oligocene and early Miocene has provided a source of sediments described as Turbidite in nature. This outstanding quality reservoir known as the Tamar Sandstones often exceeds 300 meters in thickness with 90% quartz arenites being derived from the mature Arabian-African craton to the south. By the late Miocene the Mediterranean is experiencing the Messinian Salinity Crisis where evaporates exceed thicknesses of over 1500 meters and cap the underlying Tamar reservoirs.

The Levant Basin covers over 47,000 square kilometers which includes the exclusive economic hydrocarbon zones of Israel, Egypt, Cyprus, Lebanon and Syria. Levant is positioned in the southeast of the

Mediterranean Sea; the basin’s boundaries extend from the Cyprus Arc to the north to the Nile Delta in the south, and from the Eratosthenes Seamount in the west to Israel’s shoreline in the east. A large portion of the Levant Basin is within the EEZ of offshore Israel.

The first well drill into the Levant Basin offshore Israel occurred in 1969. Although over 500 wells have been drilled both on and off shore in Israel only 50 occur in the offshore. First discovery of hydrocarbons (gas) occurred in 1999 at Noa followed by Mari B in 2000. It was not until 2009 when Noble et.al made the first major gas discovery at Tamar which was followed up by the Giant Gas Field Leviathan. Noble continued their success with the drilling of additional gas discoveries with Dalit, Aphrodite, Dolphin, Tanin and Karish. All were multi-TCF gas fields. Shimshon and Myra were discovered in 2012 by Isramco. The super-giant gas field Zohr was drilled by Eni in 2015 in Egyptian waters. In total over 77 TCF of proved recoverable reserves have been discovered.

In 2013 the Tamar gas field was placed on production at over 1.25 BCF per day. With further development the production should exceed 2 BCF per day.

The Levant Basin talk will briefly touch on the exploration history and recent successes certainly as it relates to Pre-salt discoveries. The geological framework will be described along with paleogeography. Geophysical characteristics will be shown. From the twelve pre salt gas discoveries made since 2009 the Tanin, Karish, Shimshon, Tamar and Zohr will be described as successful case histories. The talk will conclude with discussion surrounding the Eastern Mediterranean Sea gas infrastructure.

BIOGRAPHY Mr. Boland graduated from Memorial University of Newfoundland with his

Bachelor of Science Honors’ degree in Geology and his Masters degree in Earth Science. During his 34 year career he has held Senior and Executive positions with both Major and Junior Exploration and Production Companies both domestically and internationally. He has explored and operated in Western Canada, Arctic Canada, Offshore Eastern Canada, South America, West, East and North Africa, South East Asia, United Kingdom onshore, North Sea, Portugal, Eastern Mediterranean, Continental US and Gulf of Mexico. Since early 2007 Mr. Boland has been the Principal of Boland Exploration Consulting where he has been providing technical evaluations, opinions, financing, energy advice and has been facilitator/broker for both startup and established energy firms worldwide. Mr. Boland is a professional member of APEGA and the CSPG.

DIVISION TALKS


OPERATIONS GEOLOGY TECHNICAL DIVISION TALK

The Importance of Drill Cuttings, and How Sample Pro Can Provide Accurate and Representative Sample DataSPEAKERWill Rieberer, President, Sample Pro Ltd.

Time: 12:00 pm Date: Thursday, May 31, 2018Location: geoLOGIC Classroom (2nd Floor), Aquitaine Tower, 540-5th Avenue S.W.

ABSTRACTDrill cuttings are a vital source of information obtained the wellbore. They are the only tangible source of information from the reservoir, and every effort should be made to obtain the best possible sample data. Many experts believe that modern unconventional reservoirs are in fact more

complex than previously thought, and that subtle complexities can lead to significant variances in production. New technology has been developed in recent years to analyze and interpret drill cuttings (and the reservoirs which they represent) - XRF, XRD, Chemostratigraphy, SEM and thin section analysis - leading to a better understanding of the complexities associated with modern unconventional reservoirs. Collecting accurate and representative sample data will not only lead to a better understanding of the reservoirs today, but will ensure that a useful data base exists if, or when, new analytical tools and techniques become available in the not too distant future. In order to improve the collection of drill cutting sample data, Sample Pro has

developed a cost effective technology which provides truly accurate and representative drill cutting samples.

BIOGRAPHY Will graduated from the University of Calgary in 1985 with a B.Sc. in Geology. In his 30+ years in the Oil and Gas industry, he has worked extensively as a wellsite Geologist In 2005, out of frustration with the quality of drill cutting samples, he began design and field testing of the first Sample Pro prototype, and has since been granted several patents in Canada and the US. Since 2007, Will has been President of Sample Pro Ltd.

30th Annual CSPG/CSEG/CAPL

10km/5km Road Race and Fun Run

Thursday, September 20, 2018

SAVE THE DATE Registration opens: May 1, 2018

To register please go to

www.cspg.org– Events– Road Race & Fun Run

Member rate: $40+gst Non-member rate: $50+gst

Student & In-Transition rate: $25+gst

REGISTRATION OPEN

29th Annual Mixed Golf Tournament

Friday, August 24, 2018

To register please go to www.cspg.org– Events– Mixed Golf Tournament

Member rate: $95+gst

Non-member rate: $135+gst

REGISTRATION CLOSES AUGUST 15, 2018

DIVISION TALKS


ALBERTA PALAEONTOLOGICAL SOCIETY DIVISION TALK

Impact of climate cycles on the paleoenvironments of early hominins in the Kenya Rift Valley

SPEAKERDr. Jennifer Jane Scott, Associate Professor, Geology, Department of Earth and Environmental Sciences, Mount Royal University, Calgary, Alberta

Time: 7:30 pm Date: May 1, 2018Location: Mount Royal University, Room B108 ABSTRACTFrom several drill cores part of the Hominin Sites and Paleolakes Drilling Program (HSPDP), this collaborative research aims to better interpret the key environmental factors affecting early hominins in the rift valley lake basins of Kenya and Ethiopia. To recognize the influence of climate on the paleoenvironments, it is essential to try to differentiate between climate cyclicity and other effects such as tectonics on the sedimentary and paleoecological record. Using trace fossils integrated with sedimentology, we have developed a stratigraphic framework for one of the cores (Baringo) using sequence stratigraphy. By applying the high-resolution Ar/Ar geochronological age model to the thicknesses of the lake cycles, delineated

best with flooding surfaces, we see that there is likely a strong climate signal recorded in these rift valley lakes. Our ongoing work now focuses on integrating paleoanthropological and paleontological data from field localities with the time-equivalent results from the core. This research helps to provide the framework needed to test hypotheses on the drivers for hominin speciation and behavioural changes through the Plio-Pleistocene in East Africa.

BIOGRAPHYJenni Scott is an associate professor in geology at Mount Royal University, and an adjunct professor at Simon Fraser University. Her research focuses on using trace fossils and sedimentology in stratigraphy and paleoenvironmental analysis. Building on her PhD research in the saline lake settings of the Pliocene to modern Kenya Rift Valley and Eocene Green River Formation, she is presently part of the Hominin Sites and Paleolakes Drilling Program in Kenya and Ethiopia. So far, she has developed a stratigraphic framework for the Plio-Pleistocene Baringo core, useful for integrating multiple paleoecological datasets. This work aims to determine if the paleoenvironments preserve evidence of changing climate and climate cycles at this important time in hominin evolution, and

to better calibrate the paleontological field evidence with the core. Her other research includes a stratigraphic, trace fossil, and sedimentological analysis of the Cretaceous Foremost, Oldman, and Dinosaur Park formations in Alberta. She is an associate editor for the Journal of Sedimentary Research and Ichnos, a board member for the International Limnogeology Association, a former treasurer for the International Ichnological Association, is a co-chair for the Lacustrine Systems theme at the upcoming AAPG conference, and will be one of the plenary speakers for the upcoming Limnogeology–Paleolimnology congress in Sweden.

DIVISION INFORMATIONThis event is presented jointly by the Alberta Palaeontological Society, the Department of Earth and Environmental Sciences at Mount Royal University, and the Palaeontology Division of the Canadian Society of Petroleum Geologists. For details or to present a talk in the future, please contact CSPG Palaeontology Division Chair Jon Noad at [email protected] or APS Coordinator Harold Whittaker at 403-286-0349 or contact [email protected]. Visit the APS website for confirmation of event times and upcoming speakers: http://www.albertapaleo.org/.

1602 – 5th St N.E.

Calgary, AB. T2E 7W3 Phone: 403-233-7729

www.tihconsulting.com e-mail: [email protected]

T.I.H. Consulting Ltd. Geologic Well-Site

Supervision



SOCIETY NEWS

STANLEY SLIPPER GOLD MEDAL 2017 - ALISON ESSERY

The Stanley Slipper Gold Medal is amongst the most prestigious awards given by the Canadian Society of

Petroleum Geologists. It was established in 1989 to honour individuals who have made outstanding contributions to the science of petroleum geology and to petroleum exploration in Canada. The award is named after Stanley E. Slipper, the founding President of the Alberta Society of Petroleum Geologists, which we now know as the Canadian Society of Petroleum Geologists. Stanley Slipper is one of the iconic early explorationists in Western Canada. Recipients of this award have made contributions encompassing one or more activities related to petroleum exploration and development. Such activities may include initiating and leading exploration programs, teaching and mentoring and developing innovative exploration concepts.

The 2017 Stanley Slipper Gold Medal recipient is Alison Edith Essery.

Alison Essery grew up in Winnipeg, Manitoba, and spent her summers as a kid hiking the Canadian Shield and collecting rocks. Professor Bill Brisbin, Chair of the Department of Earth Sciences at the University of Manitoba, visited Alison’s high school and spoke to the students about degrees in geology. Inspired, she enrolled

in the University of Manitoba in the Fall of 1972 and graduated with an Honours B.Sc. in Geology in 1976.

Alison had made the most of her time in university. She worked the summer of 1974 north of Lac la Ronge for the Saskatchewan Department of Mines. In the summer of 1975 she worked for Imperial Oil, picking 20 formation tops from 700 wells in their Cold Lake heavy old project using microfiche cards. This tedious task was made bearable by the close proximity of the Rocky Mountains to which she escaped every weekend for hiking and climbing.

Alison’s view of her future employment situation was: “I had also applied to Parks Canada and was set to be interviewed for a warden’s job in Banff. But I was also keen to work at Shell, because I was so impressed by their early structural and field mapping work and their (now classic) publications … and a job with Shell had opportunities for overseas assignments.” Shell won out, and Alison started work in Calgary in summer 1976.

She was the operations geologist on five East Coast Canada offshore wells, most significantly, the Penobscot discovery, offshore Nova Scotia. She characterized this as being “thrown in the deep end, spending several months in front of a microscope, logging cuttings from offshore wells.” Alison was the first woman to sit an East Coast offshore rig – Penobscot L-30 on the SEDCO H semi-submersible. Prior to this, Alison had trained three male geologists in succession on the interpretation of cuttings and log tops so they could go to the offshore rig to call core points on her wells, as there were no accommodations for females. The drilling manager claimed that the insurance company wouldn’t insure Shell to let her work on the rig. Lorne Kingwell, Manager - Frontier told Drilling to “spend the money”. She was able to core the only metre of oil-bearing reservoir in the well, which, in hindsight, was drilled on the very down-dip edge of the oil column.

Her next assignment in Northern Alberta/

BC Foothills was challenging. This was a tough area to interpret, with few wells, old 2D lines and structures transitioning between thin-skinned thrusting (cross-sections that could be balanced) into box-folded Triassic structures with less ‘boundaries”.

Alison’s strong interest in the Triassic reservoirs in Western Canada grew in the 1980s when she was introduced to the use of geophysical techniques that could be integrated with wells, cores and reservoir models to map amplitude prospects at the loop level - and then to successfully drill them. During this period, she and her team drilled several economic Halfway, Doig, Charlie Lake, Cadomin and Paddy oil and gas discoveries.

In 1983 Alison relocated to den Hague, Netherlands where she was deployed as a Senior Geologist on Shell International’s Prospect Evaluation and Forecasting Team. Alison saw this exposure to international activities as a “Deep Dive” into exploration petroleum geology. Shell International needed analogs for evaluating their exploration plays and prospects through a worldwide comparison. Alison was told to build on her hands-on Canadian exploration/mapping experience and to apply that practical experience to document plays, capture retiring geologists’ ideas and add plays that might have been overlooked. She worked quickly, one basin every three to four weeks, through the Far East, Middle East, Africa, South America and the Arctic, summarizing play types, documenting their reservoir potential, risks - geologically, politically and economically – as captured in a computer database. Eventually she had documented and evaluated 300 existing plays and identified 50 new plays worldwide including one in Colombia that was put on the drilling schedule.

Following her return to Canada, Alison briefly held a variety of leadership positions including on the East Coast team (drilled the Cretaceous Panuke discovery) and on the Triassic and Kiskatinaw plays. The latter position allowed her to work beside Glen


SOCIETY NEWS

Andrews, an expert stratigrapher, while he developed his estuarine model for the Kiskatinaw. This gave her encouragement to dig into the Doig facies model to demonstrate that the Doig sandstones were more complex than simple channels or “incised valley-fill bodies”.

Alison’s first Development assignment came in 1991 with the Waterton Foothills team when she really got to understand the importance of managing cash flow and capital costs while meeting forecasts. Alison worked on production from the thick, highly prolific gas-bearing Mississippian/Devonian carbonate reservoirs, characterized by low porosity with a high degree of fracturing. Working with the team’s geophysicists, two vertical wells were drilled as well as three horizontals, proving up 70 bcf of new reserves.

In 1996 Alison again went international, this time with Shell Oil in New Orleans, once again pursuing wildcat exploration, but this time in onshore/offshore areas for both deep water and shallow water sediments in the Gulf of Mexico. She applied sequence stratigraphic concepts, amplitude characterization and trap sealing concepts for mapping prospects on 3D seismic - a great lead-in to her next assignment in Canada. In 1999 Alison was assigned to a multidisciplinary team involving staff from Shell, ExxonMobil and Chevron evaluating the prospectivity of the Nova Scotia deepwater. She was one of several interpreters using 2D and 3D seismic to map amplitude and structural traps involving the application of sequence stratigraphy, salt tectonics, basin modelling and reservoir quality prediction techniques. She organized and facilitated risk and volumetric analysis/consensus among all Canadian partners for the land sale bids which led to the drilling of a deepwater wildcat in 1000 m water depth.

Following an assignment as Team Lead for the Sable Basin geoscience group, Alison wanted to get back to working Western Canadian geology. She joined Burlington Resources in 2005 where she pursued Triassic plays in B.C. and Alberta, including the development of the Brassey Pool and other Doig prospects. After Burlington’s integration with ConocoPhillips, she became Team Lead for the Elmworth

Triassic team that drilled several wells based on integrated geology and 3D seismic interpretation. Her team led the promotion of Montney development in the Cutbank Deep Basin area, following on Encana’s Swan development. Alison also developed a forced regression model of clinoforming Halfway/Doig and presented a paper entitled “Predictive Stratigraphic Mapping of Thick Triassic Doig Sandstones in B.C. and Alberta” at the 2009 Convention in Calgary.

In late 2010 Alison was asked to join a start-up, Tangle Creek Energy, as a Founder and Vice-President of Exploration. The company’s production has grown from 1000 boe/d to over 8500 boe/d today. 400 net sections of land are held containing more than 350 potential drilling locations and reserves of 53 mmboe. More than 100 horizontals have been drilled over six years. According to Alison: “Our successful exploitation of the Dunvegan Formation has been accomplished through passionate geological work. We pride ourselves on building very good geological models through the integration of core, cuttings and thin sections with log analysis, reservoir geology and facies models. Net pay maps are hand drawn with geological facies models in mind, which can change from area to area. Our Montney acquisition was based on intense evaluation of oily Montney data to find geological opportunities that have not been developed to their potential.”

Alison hasn’t slowed down. She has in recent years been more involved in volunteering with the CSPG. As well, she was given permission to discuss some of her work. In 2014 she presented CSPG talks on the Dunvegan play and the Nipisi Slave Point reservoir model. Alison likes to look at old plays or production in a different light or with a twist on a geological model or using new technology. She states, “How many times have “tired” basins been resurrected by a new play concept or a different technology?” Her advice - keep reading, learning and applying a wide range of ideas and technologies.

In retrospect, Alison expresses gratitude to the companies she has worked for “allowing me to spend time learning the plays, figuring out the risks and staying current on technology. We got to apply new concepts

and visit outcrops so that we could take the 3D visualization back with us to our plays. I was able to pursue my passion for geology and have great conversations with inspiring creative geologists. I hope that I have been able to pass on that enthusiasm to others I have mentored. Prospectivity is still the creation of the geologist. Lots of hurdles exist along the way but it’s always a learning experience and sometimes success is not far behind. All the crazy geology discussions I’ve had in remote outcrops have been worthwhile”.



SOCIETY NEWS

IN MEMORIUMPrepared and submitted by his friends and colleagues,

Fred G. Rayer, Kirk G. Osadetz and Ashton F. Embry.

John David Harper (March 21st, 1939 to October 24th, 2017)

Dr. John D. Harper, an energetic, much beloved and passionate member of Calgary’s geological

community, the CSPG and many other scientific and professional organizations, died suddenly in Calgary, October 24, 2017 at the age of seventy-eight. With his passing, our community lost a notable scientist, science educator and a “force of nature”. Born in Toronto March 21st, 1939, John was a graduate of the University of Toronto (B.ASc. ‘6T1, and M.ASc. ‘6T4). He received a Doctorate from Brown University in 1969 for his dissertation on carbonate and clastic sedimentology.

John’s career, like his energy and enthusiasm were almost without limit. His work as an academic, scientific and industrial geoscientist spanned almost half a century. His experience was geographically global, stratigraphically unrestricted and his insights and analyses were imaginative and innovative, whether working for Shell companies (1968-1976) in a variety of basins, with various responsibilities, or as the V.-P. of special projects and international studies for Trend exploration, addressing exploration

challenges in Indonesia and the Philippines. As a consultant, John was the passionate creator of an innovative “Hydrocarbon Atlas” that many companies used to complement more standard exploration tools. John brought great integrity and intellectual honesty to all of his work. More recently he was successively, Professor of Petroleum Geology and Sedimentology at Memorial University of Newfoundland (1987-1998), a senior geological advisor at Alconsult International Ltd. (1999-2001), Conoco Phillips Canada (2001-2009), and GeoReservoir Inc. John also served as the Director of the Geological Survey of Canada in Calgary.

John was a Fellow of both the Geological Association of Canada (1994) and the Geological Society of America (1979), as well as a CSPG Tracks Award recipient (1977). He was a dedicated member and Newfoundland and Labrador representative on the CSPG National Liaison Committee (1989-1998). He actively contributed to the success of CSPG, GAC and other scientific meetings as a Presenter, Session Chair and Organizer. He received best paper (1999) and honourable mention (2001) awards for presentations at CSPG Annual Meetings. His many, almost 100, scientific contributions to meetings, technical programs like the CSPG luncheons and the peer-reviewed literature span six decades (1968-2014). He was an active member of both APEGA and APEGN.

John was a dedicated teacher who loved to share his passions for work and recreation with his family, students, colleagues and the public. He loved Science, the outdoors and outdoor pursuits, especially, skiing, canoeing and “exploring”. He volunteered with the Canadian Ski Patrol System for nearly 40 years where his rescues and interventions were as varied as his career, being often commonplace but sometimes truly lifesaving. He taught avalanche safety to many who continue to share his love of nature and the mountains more safely

because of his instruction. He coached youth sports programs and was an involved member of various civic and community organizations and programs.

John was a dedicated husband and an affectionate patriarch. He imparted his penchant for leadership by example and social responsibility on his son’s and their families. John is survived by his beloved wife of 55 years, Cathy, his children and their families: son David, wife Leanne and grandchildren Ian and Diana of Denver, Colorado; and son Tim and his wife Alison who live in Yukon Territory. He was a fine Gentleman, an outstanding community member and an enthusiastic scientist. He and his energy will be much missed.

Clastic Exploration School October 22-26, 2018, Calgary, Alberta

Instructors: David James, Jim Barclay & Andy Vogan Member rate: $2500 Non-Member rate: $2700

Course Overview This 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 senior G/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 depositional settings 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 a robust stratigraphically and facies based exploration model to guide a drilling program. Core correlation and field 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.

Note from the Instructor(s): After a three + decade run, David decided to wind down the school at the close of the October 2017 CSPG class. But as famously stated “There are strange things done in the midnight sun” and that James is back could be one of them. That is because Jim and Andy, together with the CSPG unexpectedly stepped forward, and offered to continue the legacy of the class into the future. It is our hope, that with a cumulated exploration experience of the instructors boosted to well over 100 years, that the class will provide benefits to geoscientists, explorationists and to the CSPG for years to come.

David James Andy Vogan Jim Barclay

For instructor biographies and more course information please go to

www.cspg.org

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