First Break April 2022 - Unconventionals and Passive Seismic

VOLUME 40 I ISSUE 4 I APRIL 2022 EAGE NEWS Board makes Ukraine statement TECHNICAL ARTICLE An overview of carbon capture and storage SPECIAL TOPIC Unconventionals and Passive Seismic

cgg.com/geoverse OUR PERSPECTIVE.FROMPLANET.ANEW SE E THINGS DI FF ERE NT LY

FIRST BREAK I VOLUME 40 I APRIL 2022 1 Editorial Contents 3 EAGE News 15 Personal Record Interview 18 Crosstalk 21 Industry TechnicalNewsArticle 35 An overview of carbon capture and storage and its potential role in the energy transition Joseph M. English and Kara L. English 41 The importance of accurate timing on land seismic data T. Dean, C. Strobbia and D. Sweeney Sp ecial Topic: Unconventionals and Passive Seismic 48 Microseismic monitoring during hydraulic fracturing treatments complements 3D geomechanics modelling Randy Hickman and Jeremy Gallop 55 Wellsite real-time geochemical and petrophysical logging in North America unconventionals Isaac Easow 61 The role of fibre-optic acoustic sensing for the energy transition Simone Re, Giorgio Tango, Sergio Del Gaudio and Alessandro Brovelli 69 Compact phased arrays for microseismic monitoring Paul A. Nyffenegger, Mark A. Tinker, Jian Zhang, Elige B. Grant, Kevin D. Hutchenson and Don C. Lawton 75 Geothermal energy extraction — economic feasibility of repurposing hydraulically fractured oil and gas wells Ruud Weijermars Feature 81 Minus CO2 Challenge 2021/2022 – Student teams evaluate potential world-class carbon storage capacity offshore Nova Scotia, Eastern Canada Arpita Chakraborty, Matheus Radamés Silva Barbosa, Ahmed Samir Muhammad Rizk, Kyle Watts, Bill Richards and Grant Wach 90 Calendar 12 cover: Quality control on the data logs performed by Geolog’s field engineer Suhandi Suhandi, Indonesia. Microseismic monitoring during hydraulicfracturing treatments complements 3D geomechanics modelling FIRST BREAK ® An EAGE Publication CHAIR EDITORIAL BOARD Gwenola Michaud (Gwenola.Michaud@cognite.com) EDITOR Damian Arnold (editorfb@eage.org) MEMBERS, EDITORIAL BOARD • Paul Binns, (pebinns@btinternet.com)consultant • Lodve Berre, Norwegian University of Science (satinder.chopra@samigeo.com)Satinder(lodve.berre@ntnu.no)and TechnologyChopra,SamiGeo • Anthony Day, (anthony.day@pgs.com)PGS • Peter Dromgoole, Retired (peterdromgoole@gmail.com)Geophysicist • Rutger Gras, (r.gras@gridadvice.nl)Consultant • Hamidreza Hamdi, University of Calgary (hhamdi@ucalgary.ca) • John Reynolds, Reynolds (Peter.Rowbotham@apachecorp.com)Peter(jrickett@slb.com)James(jmr@reynolds-international.co.uk)InternationalRickett,SchlumbergerRowbotham,Apache • Dave Stewart, Dave Stewart Geoconsulting Ltd (djstewart.dave@gmail.com) • Femke Vossepoel, Delft University of Technology (f.c.vossepoel@tudelft.nl) • Angelika-Maria Wulff, Kuwait Oil Company (AWulff@kockw.com) EAGE EDITOR EMERITUS Andrew McBarnet (andrew@andrewmcbarnet.com) MEDIA PRODUCTION Saskia Nota (firstbreakproduction@eage.org) PRODUCTION ASSISTANT Ivana Geurts (firstbreakproduction@eage.org) ADVERTISING INQUIRIES corporaterelations@eage.org EAGE EUROPE OFFICE PO Box 59 3990 DB Houten The Netherlands • +31 88 995 5055 • eage@eage.org • www.eage.org EAGE RUSSIA & CIS OFFICE EAGE Russia & CIS Office EAGE Geomodel LLC 19 Leninsky Prospekt 119071, Moscow, Russia • +7 495 640 moscow@eage.org2008 • www.eage.ru EAGE MIDDLE EAST OFFICE EAGE Middle East FZ-LLC Dubai Knowledge Village Block 13 Office F-25 PO Box 501711 Dubai, United Arab Emirates +971 4 369 3897 • middle_east@eage.org • www.eage.org EAGE ASIA PACIFIC OFFICE UOA OfficeCentreSuite 19-15-3A No. 19, Jalan Pinang 50450 Kuala Lumpur •Malaysia+603 272 201 40 • asiapacific@eage.org • www.eage.org EAGE AMERICAS SAS Calle 93 # 18-28 Oficina 704 Bogota, Colombia • +57 1 4232948 • americas@eage.org • www.eage.org EAGE MEMBERS CHANGE OF ADDRESS NOTIFICATION Send to: EAGE Membership Dept at EAGE Office (address above) FIRST BREAK ON THE WEB ISSNwww.firstbreak.org0263-5046(print) / ISSN 1365-2397 (online)

Pascal Breton Secretary-Treasurer Aart-Jan Wijngaardenvan Technical Programme Officer Alireza Malehmir Chair Near GeoscienceSurfaceDivision Lucy Slater Chair Oil & GeoscienceGasDivision Jean-Marc Rodriguez Vice-President Dirk Orlowsky President

Peter Rowbotham Publications Officer

2 FIRST BREAK I VOLUME 40 I APRIL European2022Association

Lucy Slater Chair

Colin MacBeth Education Officer

Alireza Malehmir Chair

Myrto Papadopoulou Young Professional Liaison

Yohaney Gomez Galarza Vice-Chair

First Break is published by EAGE Publications BV, The Netherlands. However, responsibility for the opinions given and the statements made rests with the authors.

Eric Cauquil Liaison Shallow Marine Geophysics

Hongzhu Cai Liaison China

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Micki Allen Contact Officer EEGS/North America

Esther Bloem Vice-Chair

Orders for current subscriptions and back issues should be sent to EAGE Publications BV, Journal Subscriptions, PO Box 59, 3990 DB, Houten, The Netherlands. Tel: +31 (0)88 9955055, E-mail: subscriptions@eage.org, www.firstbreak.org.

Giovanni Sosio DET SIC Liaison Aart-Jan van Wijngaarden Technical Programme Officer

Hamdan Ali Hamdan Liaison Middle East

Koya Suto Liaison Asia Pacific Catherine Truffert Industry Liaison Panagiotis Tsourlos Editor-in-Chief Near Surface Geophysics

SUBSCRIPTIONS First Break is published monthly. It is free to EAGE members. The membership fee of EAGE is € 80.00 a year (including First Break, EarthDoc (EAGE’s geoscience database), Learning Geoscience (EAGE’s Education website) and online access to a scientific journal. Companies can subscribe to First Break via an institutional subscription. Every subscription includes a monthly hard copy and online access to the full First Break archive for the requested number of online users.

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Francesco Perrone Member Matteo Ravasi YP Liaison

Vladimir Ignatev Liaison Russia / CIS Andreas Kathage Liaison Officer First Break Musa Manzi Liaison Africa

Michael Peter Suess Immediate Past Chair; TPC Erica Angerer Member Wiebke Athmer Member Juliane Heiland TPC Tijmen Jan Moser Editor-in-Chief Geophysical Prospecting

Deyan Draganov Technical Programme Officer

Caroline Le Turdu Membership and Cooperation Officer

COPYRIGHT & PHOTOCOPYING © 2022 EAGE All rights reserved. First Break or any part thereof may not be reproduced, stored in a retrieval system, or transcribed in any form or by any means, electronically or mechanically, including photocopying and recording, without the prior written permission of the publisher.

George Apostolopoulos Immediate Past Chair

Florina Tuluca Committee Member Oil & Gas Geoscience Division

of Geoscientists & Engineers Board 2021-2022

Jonathan Redfern Editor-in-Chief Petroleum Geoscience

HIGHLIGHTS

Support colleaguesfor in Ukraine LC Kyiv is one of the oldest (and continuously operating) EAGE Local Chapters, established in 2004 with around 500 members including students. It has a notable record of supporting its local geoscience com munity and EAGE events, winning the Best LC prize in 2011 and 2014, and receiving an honourable men tion in 2019 in recognition of their work.In support of Ukraine’s geoscience community, EAGE is introducing a special fee waiver programme for the country’s geoscientists and engineers. Until further notice, we will welcome Ukrainian colleagues to participate in our workshops, conferences and education programmes, both in person and online, free of charge. Ukrainian colleagues wishing to take advantage of this programme are asked to send their applications to membership@eage.org under the heading of Ukraine fee waiver. This initiative has the support of PACE, our Programme for Association and Cooperation in Earth Sciences.

FIRST BREAK I VOLUME 40 I APRIL 2022 3

Secrets of Madrid await you04 Black swan enigma explained09 Weighing future for students14

The EAGE Board unanimously express es our shock and dismay at the ongoing Russian military invasion of Ukraine and offer our support to the millions of people affected, in particular the geoscience community and our Local Chapter in Kyiv. We believe that scientific endeavour should in principle transcend politics. In that respect EAGE’s mission is to pro mote a truly international forum for the sharing of geoscience and engineering knowledge in all its activities. We are active in over 100 countries worldwide, guided by a policy of respectful coop eration.However, we have to draw the line at these hostilities and make clear that the Association deplores this act of war and the disastrous human consequences. We therefore condemn the Russian attack on Ukraine to the utmost, and support any action to stop further escalation of the violence and all efforts to find a peaceful solution. In addition to complying with all sanctions mandated by the EU, the EAGE is taking immediate steps to suspend its commercial relationship with Russian entities and the organ ization of international events in the name of the EAGE in the Russian Federation.Weunderstand that individual sci entists in Russia may have no role in the current sequence of events; therefore, we continue supporting and servicing Russian members as individuals and as part of the scientific community. Our urgent wish is that the con flict is brought to a rapid conclusion without further unnecessary bloodshed and destruction. In the meantime we must stand firm with the international community in our condemnation of this senseless armed aggression. Ukraine landscape.

EAGE Board Ukraine Statement

The Madrid Basin is an intracraton ic continental basin that was filled up mainly by alluvial, fluvial, evaporitic and non-evaporitic lacustrine deposits of Ceno zoic age. The geothermal potential of the overall basin has been assessed to a depth of 5000 m — as Prof Alfonso Muñoz Martín (UCM) and Antonio Olaiz Campos (Repsol) will illustrate — resulting in one of the most favorable geothermal environ ments identified to date in Spain. From the distant past to future devel opments ‘Geosecrets of Madrid’ promises to be an intriguing eye-opener, allowing guests time for some excellent networking too. All attendees can join on Wednesday 9 June at the EAGE Dome and online. Read more about this session and all the community activities planned at the upcoming EAGE Annual on the event website at www.eageannual2022.org.

The Geominero Museum, housed in the headquarters of the Spanish Geology and Mining Institute of Madrid, for example, hosts a treasure of geological and mining heritage including minerals, rocks and fossils from all over Spain and its for mer colonies. Silvia Menéndez Carrasco (Instituto Geológico y Minero de España) will guide us on a virtual discovery jour ney of the highlights. The Museum is well worth a visit even just to experience the venue itself, with its breathtaking hall with a stained glass roof, and to top it off the entrance is free! We will also talk about the fossil ver tebrate deposits of Cerro de los Batallones, not far from Madrid, which constitute one of the most outstanding discoveries in paleontology - a memory of the prehistoric life of this area. Since December 2021, a good collection of fossils from this excep tional site are permanently exposed in the Museo Arqueológico y Paleontológico Regional in Alcalá de Henares (Madrid).

Bogotá to host unconventional resources workshop

A Fourth EAGE Workshop on Uncon ventional Resources is to be held in Bogotá, Colombia on 1-2 December 2022. It will provide an opportunity to show current and potential oil and gas projects in the region. This should be of interest not just to regional com panies but to international operators and service providers who are active and see potential in unconventional resources. Development, research and invest ment in unconventional resources have increased in the last decade. Latin Amer ica is in the early stage of developments compared with other unconventional basins, but is showing excellent results in production and has been widely rec ognised especially in Argentina, Mexico and Colombia where the possible addi tion to hydrocarbon reserves is being perceived as significant. Together with Mexico and Brazil, these are the coun tries with the largest reserves of tech nically recoverable unconventional gas. Stay tuned on the event website for more information on the call for abstracts and registration for this valua ble workshop. Visit the event website for more details! Spectacular hall of the Museo Geominero. Credit: IGME.

Did you know that the subsurface of Madrid is crossed by a network of hun dreds of kilometres of hidden galleries which drain and collect water from an underground siliciclastic aquifer? These are popularly known as ‘viajes de agua’ (water ways).

Time to discover the geosecrets of Madrid

A very special session awaits you at the 83rd EAGE Annual Conference & Exhibition this year. With the opportunity of hosting the event in the Spanish capital, our EAGE Local Chapter Madrid will have the pleasure of introducing you to some of the hidden gems of the city’s rich historical and geological landscape.

EAGE NEWS 4 FIRST BREAK I VOLUME 40 I APRIL 2022

Prof Pedro Martínez-Santos (Universidad Complutense de Madrid), will share the secrets of this resourceful system, designed and constructed by the Arabs in the 9th century to supply water to a small village, by then named Magerit, the precursor of Madrid City and origin of the current city name. If you are attending the conference in person in June, you will also have the opportunity to see first-hand some of the wonders revealed in this session.

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EAGE NEWS 6 FIRST BREAK I VOLUME 40 I APRIL 2022 EAGE Online Education Calendar FOR THE FULL CALENDAR, MORE INFORMATION AND REGISTRATION PLEASE VISIT WWW.EAGE.ORG AND WWW.LEARNINGGEOSCIENCE.ORG. START AT ANY TIME VELOCITIES, IMAGING, AND WAVEFORM INVERSION - THE EVOLUTION OF CHARACTERIZING THE EARTH’S SUBSURFACE, BY I.F. JONES (ONLINE EET) SELF PACED COURSE 6 CHAPTERS OF 1 HR GEOSTATISTICAL RESERVOIR MODELING, BY D. GRANA SELF PACED COURSE 8 CHAPTERS OF 1 HR CARBONATE RESERVOIR CHARACTERIZATION, BY L. GALLUCCIO SELF PACED COURSE 8 CHAPTERS OF 1 HR 5 APR5 MAY DATA SCIENCE FOR GEOSCIENCE, BY J. CAERS EXTENSIVE COURSE * 4 CHAPTERS OF 1-2 HRS 5-8 APR MITIGATING BIAS, BLINDNESS AND ILLUSION IN E&P DECISION MAKING, BY M. BOND SHORT COURSE 4 CHAPTERS OF 4 HRS 12-15 APR GEOLOGICAL INTERPRETATION OF GEOPHYSICAL DATA FOR MINERAL EXPLORATION, BY M. DENTITH SHORT COURSE 4 CHAPTERS OF 4 HRS 18 APR LOW FREQUENCY SEISMIC ACQUISITION ON LAND, BY B. DUIJNDAM DLP WEBINAR 1 CHAPTER OF 1 HR 20 APR IN PURSUIT OF INCREASED RESOLUTION WHILE PRESERVING AMPLITUDE FIDELITY, BY J. REILLY E-LECTURE WEBINAR 1 CHAPTER OF 1 HR 21-22 APR MEDIUM AND LOW-GRADE GEOTHERMAL ENERGY: GEOSCIENCE AND GEOMECHANICS, BY G. WACH & M. DUSSEAULT (ONLINE EET) SHORT COURSE 2 CHAPTERS OF 4 HRS 25 APR SEISMIC ATTENUATION: FRIEND OR FOE, BY M. VARDY E-LECTURE WEBINAR 1 CHAPTER OF 1 HR 25-27 APR SEISMIC DIFFRACTION – MODELING, IMAGING AND APPLICATIONS, BY T.J. MOSER SHORT COURSE 3 CHAPTERS OF 4 HRS 27-29 APR SUB-SURFACE UNCERTAINTY EVALUATION (SUE), BY M. AGARWAL SHORT COURSE 3 CHAPTERS OF 4 HRS

The Second EAGE Workshop on Enhanced Oil Recovery (EOR) in the Americas will be held in Bogotá, Colombia on 12-14 October 2022. We are inviting experts to provide insights into all phases of an EOR project: research, planning, field imple mentation, and surveillance. As existing oil fields mature, including the unconven tionals, EOR methods have been gaining significant momentum globally. Colombia and the other major oil producing Latin American countries are no exception to theseThetrends.workshop will offer new funda mental and practical ideas about the EOR methods and provide first-hand experience from successful operators, service com panies, government representatives and academia. There is value to be unlocked in every aspect of an EOR project. The Technical Committee invite prac titioners, innovators and industry experts to contribute to this workshop and share their achievements and challenges, lay out big innovative ideas and seek new alliances to jointly develop a road for the future. Contributors are welcome to submit abstracts of 2-4 pages in length before 1 July 2022 on the following topics: EOR/IOR techniques; Theoretical modelling and numerical simulation for EOR; Reservoir and field management for EOR; Impact of chemicals and fluids from EOR operations on production facilities; Case studies of the EOR/IOR methods in the Americas; and Newly emerging and related technologies. Visit the event website for more details! A field implementation.

3 MAY3 JUL GEOLOGICAL CO2 STORAGE, BY A. BUSCH, E. MACKAY, F. DOSTER, M. LANDRO, P. RINGROSE EXTENSIVE COURSE * 7 CHAPTERS OF 1 HR 3-6 MAY INTEGRATED METHODS FOR DEEP-WATER RESERVOIR CHARACTERIZATION, BY J.R. ROTZIEN SHORT COURSE 4 CHAPTERS OF 5 HRS

9 MAY9 JUN DEVELOPING DEEP LEARNING APPLICATIONS FOR THE OILFIELD: FROM THEORY TO REAL WORLD PROJECTS, BY B. MONTARON EXTENSIVE COURSE * 5 CHAPTERS OF 1 HR

12-13 MAY INTRODUCTION TO HEAVY OIL: GENESIS, PROPERTIES, DISTRIBUTION, RECOVERY TECHNOLOGIES AND UPGRADING, BY A. SHAFIEI SHORT COURSE 2 CHAPTERS OF 4 HRS

Enhanced oil recovery is focus of Bogotá workshop

* EXTENSIVE SELF PACED MATERIALS AND INTERACTIVE SESSIONS WITH THE INSTRUCTORS: CHECK SCHEDULE OF EACH COURSE FOR DATES AND TIMES OF LIVE SESSIONS

5-6 MAY MACHINE LEARNING IN GEOSCIENCES, BY G. SCHUSTER SHORT COURSE 2 CHAPTERS OF 4 HRS

16-20 MAY INTRODUCTION TO DATA ANALYSIS: CONCEPTS AND EXAMPLES, BY R. GODFREY SHORT COURSE 4 CHAPTERS OF 4 HRS

Gravitational wave detectors and quantum computing enthral LC Netherlands EAGE Local Chapter Netherlands ended its year’s activities in December with a virtual webinar on ‘Seismic noise and subsurface characterization for gravity wave detectors’ and started up again in February with a session on ‘Quantum Computing for Geoscience’. Rita Streich reports: Our Decem ber event started with a review of the Chapter’s activities over the year, and an outlook on 2022, given by our pres ident Diego Rovetta. We also celebrated together the best LC Newcomer 2021 award, which we had received from EAGE. The monetary award that came with this recognition will be used for the Chapter’s next in person event. It was then the turn of our guest speaker Prof Dr Jo van den Brand from Nikhef, the Dutch National Institute for Subatomic Physics, to present the latest developments on gravitational wave detectors. He reviewed the interfero metric technology used for measuring gravity waves, and the groundbreaking first detection achieved by the LIGO Gravitational-Wave Observatory in 2015. He showed the less-known series of events detected since then, related to black-hole collisions and neutron star explosions. He then talked about the plans for Einstein Telescope, the next-generation underground gravity wave detector that aims to boost the sensitivity by about a factor of 100, such that thousands of transient gravity wave events can be observed every year. He discussed seismic investigations done at Terziet in Limburg, the Euregio MeuseRhine candidate site for setting up the Einstein Telescope. Suitable sites have to exhibit lowest possible levels of seismic noise.Following the presentation, a range of questions included comparison of spacebased and Earth-based antennas, which complement each other; source location for gravitational waves in analogy to seismic source location; identification of short-term events in continuous time series, which exploits specific waveform characteristics and increasingly makes use of AI; and the scientific as well as political debate around selecting the Einstein Telescope site. Dong Zhang reports: For the meet ing on ‘Quantum Computing for Geosci ence’ we had two invited speakers, Prof Matthias Möller from Delft University of Technology and Dr Marcin Dukalski from the Aramco Global Research Cen tre inProfDelft.Möller gave a brief introduction on the development of quantum comput ing, with the focus on recent activities in the Netherlands. He mentioned that there exist two distinct types of quantum com puting technologies: gate model-based quantum computing and quantum annealing. Gate model-based quantum computers are universally programmable and are meant, one day, to solve a wide range of problems which are out of reach for the classical digital computers. How ever, these quantum computers are still in their infancy, with small, noisy computers and only a few algorithms known today. Quantum annealing, though specific to optimisation problems, can be applied to many different use cases, such as solving multi-modal optimisation problems in areas such as deep learning, logistic network design, finance, etc. At the end of his talk, he demonstrated the idea of using quantum annealing with a simple car paint shop optimisation example. Dr Marcin Dukalski for his talk introduced a specific quantum anneal ing machine, which is accessible as a commercially available cloud computing service. He explained that quantum annealers do not ‘compute’ the result in a classical sense. Instead, they ‘quantum tunnel’ towards and settle in a physical lowest energy quantum state. That is to say, math is replaced by an actual phys ical optimisation experiment carried out on a programmable quantum annealer. He then showed some opportunities and toy-problems of early applications in geoscience using quantum computing in a hybrid mode with a classical computer and algorithm as a driver. For example, he discussed the determining a local per meability profile in a hydrologic inverse problem, linearized 2D FWI and sound velocity profile inversion. Most impor tantly, he described the latest inter-dis ciplinary collaboration on residual static estimation using quantum annealing. He concluded by promising a very exciting future and a lot of interesting work for geoscientists who may wish to be involved in quantum computing.

EAGE NEWS FIRST BREAK I VOLUME 40 I APRIL 2022 7

Lively discussions followed after the two talks, with questions ranging from on how to get started with quantum computing to deep technical ones per taining to the theory of inverse problems in general. It seemed that most of the attendees were quite curious about how to transfer the mathematical problem to its corresponding quantum annealing problem, or whether there are less imme diately obvious geophysical applications such as seismic multiple estimation. Both speakers believe that there is a very promising future for quantum comput ing when used for solving geophysical inverse problems in the coming years. These talks and the insightful dis cussion with the audience that followed are available on the EAGE YouTube channel, for anyone who is interested in this exciting new technology. Stay informed about the chap ter’s activities through the LinkedIn page Netherlands@gmail.combergroups/13690220/https://www.linkedin.com/andbecomeamembysendinganemailtoeageLC.

QPU – quantum processing unit.

• Late Paleozoic supradetachment basin configuration in the southwestern Barents Sea — Intrabasement seismic facies of the Fingerdjupet Subbasin — Julie Linnéa Sehested Gresseth et al.

Editor’s Choice article:

• A sneak peek to the upcoming digitalization-related EAGE events globally so you can plan ahead

• A special section where you can join the AI community and be part of the knowledge sharing group focused on artificial intelligence and machine learning

You might be wondering what valuable information you can derive from the page?

• Investigating soil conditions around buried water pipelines using very-low-frequency band alternating current electrical resistivity survey — Motoharu Jinguuji and Toshiyuki Yokota

Editor’s Choice article:

Digitaliza tion

That’s why we launched the

• A snapshot of the available online courses and other learn ing resources related to digitalization

Stay connected and updated on the latest happenings in digitalization! Explore the page at eage.org/digital and let us know what you think. You can reach us at communities@eage.org for comments and suggestions. Discover the new EAGE Digitalization Hub! Visit our new Digitalization Hub to find everything EAGE does around the topic.

• First application of a new seismo-electric streamer for combined resistivity and seismic measurements along linearly extended earth structures — Cesare Comina et al.

• Highlights from First Break editions tackling digitalization and how to publish your work in special issues

• The syn-rift tectono-stratigraphic record of rifted margins (Part II): A new model to break through the proximal/distal interpretation frontier — Pauline Chenin et al. Association. EAGE Hub. It is dedicated space for all digitalization-related EAGE activities including upcoming events, e-learning/ courses, community activities, resources, awards, and other digitalization-related news.

• Easy access to past events and their proceedings archived in EarthDoc

• Competition between 3D structural inheritance and kinematics during rifting: Insights from analogue models — Frank Zwaan et al.

EAGE NEWS 8 FIRST BREAK I VOLUME 40 I APRIL 2022 Near Surface Geophysics (NSG) is an international journal for the publication of research and developments in geophysics applied to the near surface. The emphasis lies on shallow land and marine geophysical investigations addressing challenges in various geoscientific fields. A new edition (Volume 20, Issue 2) will be published in April, featuring seven articles.

CHECK OUT THE LATEST JOURNALS OUR JOURNALS THIS MONTH NSG BR DigitalizationEAGE’sIntroducingNew Hub In the incredibly fast-paced digital transformation era we are living in, EAGE recognises the importance of keeping you informed of all the opportunities available via the

• Stochastic electrical resistivity tomography with ensemble smoother and deep convolutional autoencoders — Mattia Aleardi et al. Basin Research (BR) is an international journal which aims to publish original, high impact research papers on sedimentary basin systems. A new edition (Volume 34, Issue 2) will be published in April, featuring twenty articles.

LC London acknowledges Artem Kashubin of PetroTrace, Yulia Biry altseva of Equinor, Celina Giersz of Stryde, Azza Salem and, of course, Karyna Rodriguez for staging this event.

2021 Minus CO2 Challenge winners announced

Congratulations are due to the Indian Institute of Technology Bombay (India) on becoming the winner of the 2021 Minus CO2 Challenge! The competition was close, with the Federal University of Bahia (Brazil), Khalifa University (UAE), and the University of Stavanger (Norway) securing the second, third and fourth places respectively. The third edition of the Minus CO2 Challenge was a great contest! Twelve teams selected from the application round based on their motivation to deal with the issue of carbon sequestration were asked to assess the carbon storage potential in deep saline aquifers and depleted hydrocarbon fields located in the Scotian Margin, Nova Scotia, Canada. Out of that, the four best teams were invited to present their find ings to the judges. See the team report on pageA81.big thank you goes to Profs Bill Richards and Grant Wach at Dalhousie University for making the datasets for this challenge available.

Black swan enigma.

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EAGE Local Chapter London was treated to a presentation in February by Karyna Rodriguez (Searcher) on bottom simulating reflectors (BSRs) and their use for the estimation of geo thermal gradients in various provinces around the Determiningworld.the geothermal gradi ent in undrilled regions remains one of the largest areas of uncertainty in fron tier basin exploration. BSRs occur at the base of a shallow gas hydrate layer in many of the world’s deep-water basins. By calculating the geothermal gradient from the sea floor to the base of the hydrate, quantitative and qualitative inference of the deeper heat flow can be made ultimately assisting basin modellers in their work. The use of BSRs can be demon strated using various seismic exam ples. In Peru the high geothermal gradient estimated in the forearc basin setting points to an active petroleum system which provides an explanation for the numerous reported oil seeps. In offshore Mexico the presence of BSRs supports a new play type asso ciated with a hybrid turbidite-con tourite system. In the Gulf of Papua a high-quality seismic dataset enables the confirmation of a BSR that does not simulate the seabed. Nassim Taleb writes about ‘black swans’ as events that appear to be anomalies but change the paradigms. This Papua ‘black swan’ suggest BSRs may be even more useful in mapping variations in heat flow and geotherm than we had previously recognised.Thepresentation was followed by a quite vivid Q&A session and interactive online communication between the speaker and the audience, where various aspects, examples and characteristics of BSR were discussed. Recording of the talk is available on the EAGE’s YouTube channel.

Finalists presenting their findings to the judges. You can enter 2022 Challenge now In the Minus CO2 Challenge, supported by the EAGE Green Fund, we challenge student teams to prepare a project development plan with zero emissions of CO2. Interested? We invite university teams of three to five students to apply for the next competition! More details and applications are available on https://eage.org/stu dents/ or via EAGE social media channels.

LC London hears how ‘black swan’ effect adds to intrigue of bottom simulating reflectors

EAGE NEWS 10 FIRST BREAK I VOLUME 40 I APRIL 2022

Bogotá student chapter meets in person at last

Since the opening of the EAGE Latin American office in 2015 in Bogotá, Colombia, EAGE Student Chapters have been established in countries such as Colombia, Mexico, Brazil, Argentina and Peru.

The EAGE/ACGGP Student Chapter of the University of America, in Bogotá, Colombia, is one such group of students who promote geoscience and geology knowledge with a focus on the petroleum industry and energy transition in an envi ronment of engineering, innovation and technology. The Chapter has been active since 8 August 2020 and together with its officers, is one of the strongest in the country. It now has an ally in Colombian Association of Geologists and Petroleum Geophysicists (ACGGP) in promoting geoscientific knowledge in the student community.Afteralmost two years of virtual activity the first face-to-face meeting of the chapter was achieved in February attended among others by the university board of directors who have been very supportive of the chapter since the begin ning. Around 40 people gathered on site, and approximately 60 people connected via online, making it quite an occasion to welcome events planned for 2022.

CHAPTERSTUDENT

The most anticipated part of the event was the forum called ‘On the Way to the Energy Transition’. Invited speakers spoke about what is happening in the industry today, energy diversification and renewable energies in the oil industry, hopefully motivating young people to study petroleum-related programmes at university.Thechapter’s president Tatiana Ballesteros and vice-president Cami lo Cubides would like to thank Arian Sarmiento (faculty advisor); the board of directors at the University of America: Mario Posada (university chancellor), Alexandra Mejía (vice-chancellor), Juan Carlos Rodriguez (engineering petroleum programme director), Maria Fernández Vega (internationalisation director), and Martha Bernal (university welfare direc tor); the forum invited speakers: Edinson Jimenez, Sebastian Gomez and Stefania Bentacurt (professors of the Department of Energies at University of America), Gustavo Gomez (manager, CPCOL), Javier Gil (CEO of Allianz Energy), John Ceron (founder and CEO, XUA ENER GY), and Flover Rodriguez (executive director, ACGGP); and the staff at the EAGE Latin American office for the suc cessful and nice gathering. To follow the EAGE/ACGGP Student Chapter, go to: LinkedIn Instagram Facebook Organising group. Sweet treats. Connecting with online participants.

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The pre-conference talk titled ‘Past, Present and Future’ covered traditional and newer trends within the field of seismic inversion, with contributions from industry experts - Brian Russell (GeoSoftware), Pat Connolly (PCA), Dario Grana (University of Wyoming), Tapan Mukerji (Stanford University Geosciences) and Esben Dal gaard (SolidGround). The recorded talk is available for general viewing at the confer ence website at seismicinversion2022.org. The main conference technical pro gramme spanned a broad range from case studies to technological advances and cov ered topics from conventional deterministic and probabilistic methods to inversion for time shifts, shallow seismic inversion, wind farm placement and FWI for safer and faster tunnel drilling. Contributions were also made on machine learning such as deep learning-based groundwater esti mation from seismic data. In the conference opener Paulo Johann, Petrobras, presented a technical overview of seismic inversion and quantitative inter pretation from a Brazilian perspective. Day 2 keynote by Odd Kolbjørnsen, Lundin Energy, discussed the common ground of the statistical models in comparison to machine learning methods. Thoughts on a future full automation of seismic inversion were presented on day 3 by keynote speak er, Ran Bachrach, Schlumberger. The technical sessions covered: Data Conditioning and Quality Control in Inver sion; Recent Innovations in Seismic Inver sion; Inversion for Lithology, Rock and Fluid Prediction; Integration of Inversion Products into Subsurface Workflows; Mul ti-component and Azimuthal Inversion; Machine Learning and FWI; and Advances in Time Lapse and Inversion. The wrap up for the conference comprised a discussion on various areas relevant to seismic inversion with panel

lists Per Avseth (Dig Science), Thomas Blanchard (Total), Esben Dalgaard (Sol idGround), and Matt Walker (BP). Discus sion was focused on the future trends in the geoscience of E&P, net-zero and green energy development and transformation, speculating on what the future can look like, what can dominate future inversion methodology, and what will remain the status-quo of the industry. Special thanks are due to the confer ence sponsors Qeye, Ikon Science, Winter shall DEA, BP, and Delft Inversion and to EAGE for organising this event.

Wide-ranging discussions at EAGE’s second meeting on seismic inversion Conference co-chairs Tanya Colwell (product strategy manager, GeoSoftware) and Øyvind Kjøsnes (lead geophysicist, AkerBP) report on the Second EAGE Conference on Seismic Inversion 7-9 February 2022.

REPORTCONFERENCE

ADDITIONS

In April proceedings of the Second EAGE Geoscience Technologies and Applications conference (GeoTech) will be on EarthDoc. This will include materials from three workshops: the 6 th EAGE Workshop on CO2 Geological Storage, the 3 rd EAGE Workshop on Distributed Fibre Optic Sensing and the 1st EAGE Workshop on Reservoir Management of Mature Fields. In total 50+ impressive papers will be presented at these events and uploaded on EarthDoc. GeoTech 2022 is dedicated to the use of integrated geoscience solutions and technologies in a wide range of subsurface, reservoir and production challenges. The proceedings will seek to examine how the latest technologies and best practices for converting geophysical data into key business value and optimal subsurface monitoring and management solutions can be leveraged. Other key themes that will be addressed include: real-time data strategies, multidisciplinary data integration and automation for interpretation and analytics.

Seeking common ground on inversion.

In addition, new issues of Near Surface Geophysics and Basin Research journals will be uploaded onto the database.

Our second online conference on seismic inversion attracted more than 100 partici pants from Europe, North and South Amer ica, Asia Pacific, and Australia regardless of the time zone differences. The technical programme included papers from 31 com panies, academia and independents.

EAGE NEWS 12 FIRST BREAK I VOLUME 40 I APRIL 2022

THIS MONTH

4 APR STUDENT WEBINAR: QUALITY CONTROL OF BOREHOLE AND SEISMIC DATA FOR SEISMIC INVERSION USING DESCRIPTIVE STATISTICS AND ROCK-PHYSICS, BY ALEXANDRO VERA ARROYO ONLINE

EAGE NEWS FIRST BREAK I VOLUME 40 I APRIL 2022 13

4-8 APR STUDENT CHAPTERS GEOQUIZ ONLINE 3-4 MAY CONFERENCE ON ENERGY TRANSITION AND RAW MATERIALS - A CHANGE DRIVEN BY STUDENTS AND YOUNG PROFESSIONALS UPPSALA, SWEDEN 9 MAY STUDENT WEBINAR: APPLICATION OF SEISMIC ATTRIBUTES AND MACHINE LEARNING TECHNIQUES FOR THE IDENTIFICATION OF FAULTS AND FRACTURES IN SEISMIC DATA, BY DIANA SALAZAR FLOREZ ONLINE 15 MAY 2022 MINUS CO2 CHALLENGE APPLICATION DEADLINE ONLINE 5 JUN LAURIE DAKE CHALLENGE FINAL ROUND MADRID, SPAIN 6-9 JUN 83RD EAGE ANNUAL CONFERENCE & EXHIBITION (STUDENT ACTIVITIES) MADRID, SPAIN 18-22 SEP NEAR SURFACE GEOSCIENCE CONFERENCE & EXHIBITION 2022 BELGRADE, SERBIA EAGE Student Calendar FOR MORE INFORMATION AND REGISTRATION PLEASE CHECK THE STUDENT SECTION AT WWW.EAGE.ORG

EAGE Local Chapters Houston and London acknowledge the organ ising committee of this full day event: Allan Willis (TGS), Kalyan Saikia (Halliburton), Artem Kashubin (Petro Trace), Carla Martin-Clave (Jacobs), Babita Sinha (GoCloudArchitect), Carrie Holloway (Schlumberger), Mariela Araujo Fresky (Shell), and EAGE staff.

EAGE Communities Portal platform hosted the meeting.

Houston and London LCs ponder path to zero CO2 emissions Local Chapter Houston and Local Chap ter London in February hosted a joint online workshop on energy transition ‘The Path to Zero CO2 Emissions –the Challenge and Opportunity’. The common topic of the day was carbon capture, utilisation, storage (CCUS) and monitoring. There were eight 35-min ute sessions presented by industry and academy speakers around the world. Our guest experts shared their insights and challenges on the possible journey to net-zero emissions by 2050. The meeting covered the current status of CCUS and future requirements for an unprecedented transformation of how energy is pro duced, stored and used globally. The meeting started off with a pres entation by Yohanes Nuwara (Research Institute of Innovative Technology for the Earth, Kyoto, Japan) on data analyt ics in CCS, followed by a talk by Shra vane Balabasqer (CarbonAnalytics) on the route to industrial decarbonisation. Then, the back-to-back presentations by Kaj van der Valk (TNO) and Ed Hoskin (Ikon Science) respectively on re-using existing wells for CO2 storage in the UK North Sea. Christopher Lloyd (University of Manchester) presented a case study on the regional exploration of CO2 storage sites in the Utsira-Skade Aquifer, north ern North Sea. Quincy Zhang (TGS) talked about geophysics for CO2 stor age in geological traps and in minerals, and Amanda Livers-Douglas (EERC) spoke about the role of geophysics in CCUS. The meeting ended with a talk by Prof Jon Gluyas (Durham Univer sity) covering the future of CCUS in the UK.The e-meeting was hosted on the new EAGE Communities Portal plat form. There were about 50 people attending each session. For those who missed the live event or would like a recap, recording of the talks is availa ble on the EAGE’s YouTube channel.

companies.Akey take-away from the discus sions was to always make sure to pursue something that you will enjoy doing, as this will help you get the most out of your career in the long run. Also it is never too late to make a career switch, or start over again (new studies) if that is what you would enjoy doing. During the final discussion we spoke about the role of fossil fuels in the ener gy transition. While the fossil industry is not going anywhere just yet, there are also lots of new and exciting opportu nities that the energy transition offers. Again we found that it all comes down to making the best decisions that fit your personal preferences, and if you follow your heart you will surely find a place where you belong. We would like to thank the EAGE Student Fund for sponsoring this event and granting some student memberships to the attendees. We are also grateful for the EAGE and LC Netherlands for their help in the promotion of the event. This greatly improved the final outcome and allowed us to reach a greater audience.

DONATE

Report on a student and young professionals geoscience networking event organised by Delft Organisation of Geophysics Students (DOGS) and EAGE Local Chapter Netherlands.

What future holds in store for students

EAGE NEWS 14 FIRST BREAK I VOLUME 40 I APRIL 2022

Great networking event for student and young professionals, hosted online.

The EAGE Student Fund supports student activities that help students bridge the gap between university and professional environments. This is only possible with the support from the EAGE community. If you want to support the next generation of geoscientists and engineers, go to donate.eagestudentfund.org or simply scan the QR code. Many thanks for your donation in advance! TODAY!

We initially planned to hold the event last November in person on campus in Delft, but new Covid restrictions forced us to move it online instead. While this was far from ideal, it did allow us to invite people from student chapters all over Europe, resulting in a great variety of nationalities attending the event. The same was true for the young profession als (YPs) invited to speak. We eventually had eight YP speakers from academia and industry, with various backgrounds. After a short introduction, the YPs were given the opportunity to introduce themselves and their company in a two-minute pitch. Some of them came from well-known companies such as Equinor, Schlumberger and Aramco, others from EBN and Fugro had to give a bit more background on exactly what their companies did. There was even one contributor from PostNL, who moved away from the geosciences after his studies.Inthe actual networking part of the event, students were split into four groups of about five people each. Each group was paired with two YPs allowing the students to ask the YPs all about their companies, career paths and career advice. After about 10 minutes the YPs would move to the next group of stu dents and the process would start all overTheagain.students could discuss a variety of topics, e.g., the best way to go about setting up a profession al network, the struggles of women in geosciences and the difference between academia and industry careers plus the possibilities of working outside the traditional geosciences (oil and gas)

For Zoë Cumberpatch , winning the Basin Research Early Career Award 2021 is the latest honour in a stellar academic career in geology, inspired by rocks and the outdoors. She joined Equinor last year, and describes herself as a ‘pole dancing petrophysicist’, a reference to her fitness regime.

Academia/industry diversity? I’m lucky enough to live and work in Norway where gender equality, at least, is refreshing. After being the ‘token female’ to some extent during my PhD, it’s incredible to work for a company that walks the walk; my team has a 50/50 gender split, and I see inspiring women across all hierarchical levels. It’s clear academia and industry have a LONG way to go to become fully diverse across the board, but amazing organisations like GeoLatinas and Black in Geoscience give me some optimism for the future.

Change to petrophysicist? As a petrophysicist I look at geology with a mathematical hat on. We’re interested in the physical properties of the rocks and fluids in the subsurface. In my line of work that’s mostly evaluating reservoirs – porosity, permeability, hydrocarbon satu ration, fluid contacts. So far I’ve worked in development, exploration and operations and every day is a learning experience.

I can’t see the industry looking the same as it does today in 20 or 30 years time, so I’ll probably be doing a job that doesn’t exist yet. I’d like to stay technical for a while, but can imagine moving into management in the future because people are more interesting than rocks (just!). Got to ask: that dance pole in your living room?

I started aerial gymnastics and pole dance in my first year of uni, became an instructor during my MSc, and now pride myself as a ‘pole dancing petrophysicist’. To me, pole is a sport (identical to skiing, snowboard ing, running up mountains and training in the gym) that challenges my body every day, just like petrophysics challenges my brain every day. In my job interview the pole was behind me and I think I intro duced myself as ‘I’m Zoë, I love rocks and pole’. Don’t knock it until you’ve tried it — life is better upside down.

Personal Record Interview CUMBERPATCHZOË FIRST BREAK I VOLUME 40 I APRIL 2022 15

What led you to geology? I was quite good across the board at school but I was happiest (and still am) when I’m outside. I was fascinated with why there were hills in some places and rivers in oth ers. My grandad’s favourite pub (Ye Olde Trip to Jerusalem, Nottingham, UK) was built into a (Sherwood) sandstone cave, so that probably helped a bit too. I was also very lucky to have had an amazing geogra phy teacher at school. He introduced me to the wonderful world of planets, volcanoes and dinosaurs. The rest is history. Is geoscience education still fit for purpose? The MSc degree I did (petroleum geo science at Imperial College) no longer exists, and has been replaced by an MSc in geo-energy with machine learning and data science. The PhD programme I did (the NERC CDT in oil and gas) at Uni versity of Manchester has been replaced by a similar one focusing on geo-net zero. Geoscience education is changing with the times. This is exactly what it should do to attract the problem solvers of tomorrow. That Basin Research award? I’m really honoured to have been awarded the Basin Research Early Career Award 2021, for our paper ‘Halokinetic modula tion of sedimentary thickness and archi tecture: A numerical modelling approach’. In short, we use a snazzy discrete element model to quantify near-salt deformation of stratigraphy under different sedimentation conditions. The paper was part of my multi-disciplinary (field work, subsurface work, numerical modelling, physical modelling) PhD project on how deep-wa ter sedimentary systems respond to salt topography. I say ‘our’ because I’m 100% behind what I refer to as the ‘collaborate don’t hate’ approach to academia. You’re a fan of mentoring? At the start of my PhD programme, while I was applying for all opportunities in sight, I came across the EAGE Women in Geoscience mentoring programme. Five years on, I still talk to my incredible mentor, Rachel, every month. She’s helped me with interview preparation, CV scan ning and prioritising work-life balance. I really would recommend searching for a mentor to anyone. I recently reached out to a petrophysicist I look up to about a potential mentoring relationship, and now we have ‘petrophysical parties’ on zoom.

Can oil and gas attract the next generation? I cannot think of a more interesting and exciting time to be part of the energy industry: which other industry is going through a complete transformation? Your career development?

The making of a pole-dancing petrophysicist

PERSONAL RECORD INTERVIEW

FIRST BREAK I VOLUME 40 I APRIL 2022 16 Make sure you’re in the know EAGE MONTHLY UPDATE MARK YOUR CALENDAR! 17-18 May 2022 Third EAGE Workshop on HPC in Americas Submit abstracts until 8 April Save on registration until 14 April 31 May - 1 June 2022 EAGE Workshop on NeutralCatalystGeoscienceQuantitativeasainaCarbonWorld Save on registration until 25 May Joinus! 28-29 APRIL • ONLINE First EAGE Workshop on Gas Exploration in Latin America CALL FOR DEADLINEABSTRACTS25APRIL! 18-22 SEPTEMBER 2022 | BELGRADE, SERBIA DIGITALIZATION YOUR HERE!STARTS CONFERENCE ON ENERGY TRANSITION AND RAW MATERIALS INVITATION BY: STUDENTS AND YOUNG AT UPPSALA UNIVERSITYPROFESSIONALS 3-4 MAY 2022 | UPPSALA UNIVERSITY Organizers SHORT COURSE AT THE EAGE ANNUAL 2022 ! MACHINE LEARNING FOR GEOSCIENTISTS WITH HANDS-ON CODING Instructor: Ehsan Naeini 6 June 2022

ShallowHybridDeepwaterAcquisitionWater Advanced Acquisition Technologies

18 FIRST BREAK I VOLUME 40 I APRIL 2022 CROSSTALK

BY ANDREW M c BARNET BUSINESS • PEOPLE • TECHNOLOGY

‘Ultimately attitude to a war is situational.’

This is of course painful and personal for the EAGE. It is happening in Europe, where the Association has its roots, with members on both sides of the conflict. Our thoughts must be with geoscience colleagues in Ukraine and the Kyiv local chapter in particular. At the same time the Association has a thriving Moscow office providing events and services to the Russian geoscience community. It is not clear where the loyalties of individual geoscientists in Russia lie. In an era of disinformation exacerbated by war, we are unlikely to find out. However, given the example set by others, the EAGE Board had little option but to protest Russian aggression by suspending for the time being all commercial dealings with Russia. Although not a perfect solution, the Board is allowing Russians to continue attending EAGE international events as individuals, in a belief that support for the Ukraine campaign is not universal in Russia. It is about as close as you can get to enabling science to transcend politics.

sanctions every ever inflicted on a country, underlines that the Russians’ brutal incursion into Ukraine is beyond reason. Not that it makes the action any more palatable, but one must assume that President Putin completely misjudged the reception his ‘liberation’ army might receive in Ukraine and the extent of the international opprobrium the assault would meet.

It is a little bit analogous to the ‘don’t mix politics with sport’ advocates epitomized by the International Olympic Committee (IOC). The IOC, a self-regulated, self-appointed body account able only to itself, a long time ago accorded itself the mission to bring nations together in sport and peace. Yet it continues to invite widespread criticism by collaborating with authoritarian regimes, most recently at the Winter Games in Beijing, China where human rights abuses caused diplomatic representatives of numerous countries to boycott the proceedings. So much for the absence of politics.

The reality is that geoscience activities, research and oper ations, cannot be neatly sequestered from the current turmoil.

At the time of writing in the third week of the Russian invasion of Ukraine, it is impossible to predict the endgame. But already this is a humanitarian crisis on a scale not witnessed in Europe since the Second World War, a mass exodus of millions of people fleeing the death and destruction of a brutal and unprovoked attack on their Commendablycountry.the EAGE Board put out a statement con demning this needless war and supporting international action to bring it to a peaceful close as soon as possible. As a matter of record, our sister society, The Geological Society of London, which counts plenty of EAGE members, did the same thing issuing a strongly worded condemnation of the Russian action. There is a cold logic to saying that if comment is to be made, then professional societies should condemn all wars equally wherever they occur. More speciously, it could be argued that no public declaration should be made because a professional scientific society should remain aloof from politics. Neither argument is tenable in this case or may be in any case. Morally there should be no distinction between a ‘just’ and an ‘unjust’ war. Mahatma Ghandi put it well – ‘What difference does it make to the dead, the orphans and the homeless, whether the mad destruction is wrought under the name of totalitarianism or in the holy name of liberty or democracy.’ Modern ‘just war’ theorists argue about the definition but recognise the contradiction. The compromise to account for a nation feeling justified in resorting to violence and killing is to talk about a ‘necessary war’ against some incontrovertible evil, e.g., versus Hitler’s Germany. Governments especially like to fall back on what might be termed the jurisprudence of war. Engaging in hostilities can be justified if sanctioned by international consensus, for example in the United Nations. Unfortunately in modern times, failure to gain UN approval has not always discouraged countries from attacking each other. Ultimately attitude to a war is situational. The chorus of international denounciation, backed by the severest economic

Consequences of war in Ukraine

You can of course add many countries in the developing world to those who may now be reviewing the practicalities of sourcing the energy transition. Poorer nations have long maintained that most such strategies discriminate against poorer countries where basic electricity and access to clean fuels for cooking are often lacking. This is borne out by the fact that serious investment in alternative energy is mainly confined to prosperous industrialised countries.Inour free enterprise world, the dramatic increase in the price of oil may actually work against spending on climate change mitigation. An extreme oil boom and bust cycle could be in play. It makes sense for commercial oil companies to take advantage of the massive profits being generated from high priced crude to get serious about adding new reserves and make up for a decade of E&PSuchunder-investment.spendinginthecurrent crisis situation could well meet with less popular resistance, even in a period when extreme climate events are becoming frequent. Optimistically the conversation about phasing out of fossil fuels could be less dogmatic and divisive. It would take account of the technological limitations of renewable energy solutions, the modest pace of change and hence the need for a more realistic timeframe for energy transition. Hopefully in this scenario the oil industry can be considered part of the solution. The agenda of those national oil compa nies heavily dependent on oil revenues may be different. They will most likely be tempted to increase production after a long period of restraint to benefit from market economics.

The ultimate irony is that more fossil fuels in the market will bring prices down and thus make spending on renewables less attractive.Obviously the seismic services sector cannot help but wonder whether anything good will emerge from today’s conflict and misery. Nearly a decade of minimal oil company E&P budgets has decimated the business, with the Covid pandemic adding to its woes. The last few weeks have seen PGS and ION Geophysi cal, two of the remaining venerable industry names still standing, in deep financial trouble and barely surviving.

There is anecdotal evidence that the rates for marine seismic surveys are picking up even if demand is still patchy. Licensing rounds continue to be announced by countries around the world with oil companies apparently prepared to invest, even if selec tively in provinces where the country’s political and fiscal regime is stable. Frontier exploration still seems to be off the table but, who knows, that could now change.

Views expressed in Crosstalk are solely those of the author, who can be contacted at andrew@andrewmcbarnet.com.

It seems unlikely that this trend goes into reverse. But nothing is certain while hostilities continue unabated in Ukraine and the Russian economy, its goods and services, are made subject to increased sanctions and isolation with no clue what retaliation might look like.

Beyond the battlefield, it seems no exaggeration that the current upheaval in the energy and commodities markets threat ens global economic, social and political order. Industry and commerce the world over was already on edge coping with the Covid-19 pandemic disruption. In the energy sector there are numerous scenarios to consider depending on how critical expected shortages in global oil and gas become. It is already a surreal world where Europe can castigate Russia for its invasion and impose sanctions, but continues business as usual importing natural gas on which many countries depend for the bulk of their energy needs. Deeply ironic too, that the explosion in prices caused by the crisis provides Russia with bonus revenue to fund its military exploits. There is little point in trying to guess how the short-term oil and gas supply issues will be handled. There are so many factors in play. No one can predict whether President Putin will at some stage cut off Russia’s gas pipelines to Europe and what measures can be taken to counter such drastic action. We know already that it is touch and go whether Euro pean consumers can stay warm until the end of winter from a cost and supply perspective. Meanwhile on the oil front, filling the immediate gap in global supplies has invited calls to Saudi Arabia and the United Emirates to turn up the taps. Others are looking for a review of current sanctions against major oil producers such Iran and Venezuela. And so on … it’s all complicated. An inescapable takeaway from the current crisis will surely be the need for governments and communities to re-evaluate the continuing necessity of oil and gas in everyday living. It will not just be the staggering rise in the cost of filling up at the petrol station, virtually every aspect of life is due to be affected, from power for industrial production and heating homes to transport and holiday travel. The tentative economic recovery from the pandemic will in many parts of the world be stopped in its tracks. The question is how this reality will be processed around the world. The plea for increased investment in renewables will doubtless be heard from those in the wealthy western industri alised countries where owning an over-priced Tesla is a badge of climate change responsibility. But such clarion calls may temporarily at least be dulled when the need for hydrocarbons to provide the necessities of life has been brought into such sharp focus. It says something that the immediate reaction of govern ments in the US and the UK has been to find ways to increase oil and gas production, the priority being to ease the concerns of their electorates. ‘An extreme oil boom and bust cycle could easily be in play.’

CROSSTALK FIRST BREAK I VOLUME 40 I APRIL 2022 19

Many geoscientists in Russia work on a daily basis in the oil and gas business. They will be impacted by the rapid retreat from Russia by the supermajors because of an ugly turn in Russian policy. That, however, is a minor if unfortunate consequence compared with the suffering in Ukraine.

Shell’s staff in Ukraine and other coun tries has been working together to manage the company’s response to the crisis locally, said the company. Shell will also work with aid partners and humanitarian agencies to help in the relief effort. ‘Our decision to exit is one we take with conviction,’ said Ben van Beurden, Shell CEO. ‘We cannot – and we will not –stand by. Our immediate focus is the safety of our people in Ukraine and supporting our people in Russia. In discussion with govern ments around the world, we will also work through the detailed business implications, including the importance of secure energy supplies to Europe and other markets, in compliance with relevant sanctions.’ At the end of 2021, Shell had around $3 billion in non-current assets in these ventures in Russia. BP will exit its 19.75% shareholding in Rosneft, which it has held since 2013. Additionally, bp chief executive officer Bernard Looney is resigning from the board of Rosneft with immediate effect. The other Rosneft director nominated by bp, former bp group chief executive Bob Dudley, is similarly resigning from the board. The resignations will require bp to change its accounting treatment of its Rosneft share holding and, as a result, it expects to report a material non-cash charge with its first quarter 2022 results, to be reported in May. The company said it could be charged as much as $25 billion for ending its Russian investments.‘Thedecisions we have taken as a board are not only the right thing to do, but are also in the long-term interests of BP,’ said chief executive Bernard Looney. BP chairman Helge Lund, added: ‘Rus sia’s attack on Ukraine is an act of aggres sion which is having tragic consequences across the region. BP has operated in Russia for over 30 years, working with brilliant Russian colleagues. However, this military action represents a fundamental change. It has led the BP board to conclude, after a thorough process, that our involvement with Rosneft, a state-owned enterprise, simply cannot continue.’

HIGHLIGHTS INDUSTRY NEWS FIRST BREAK I VOLUME 40 I APRIL 2022 21

Equinor will pull out of its joint ven tures in Russia and stop investing in the country. The company, which has been in partnership with Rosneft since 2012, said that it had $1.2 billion of assets in Russia. ‘We regard our position as untenable,’ said Equinor’s president and chief executive AndersWintershallOpedal. Dea has decided not to advance or implement any additional gas and oil production projects in Russia and to write off its financing of Nord Stream 2 totalling around 1 billion euros. Winter shall Dea remains active in GASCADE Gastransport. GASCADE operates a 3200 km gas pipeline network in Germany: critical infrastructure for gas transport in Germany and Europe. Wintershall Dea remains involved in the existing Yuzhno Russkoye and Achimov natural gas pro duction projects in Siberia. The projects produce natural gas for European energy supply.ExxonMobil is planning to cease oper ations on the Sakhalin-1 project in Russia after the country’s invasion of Ukraine. ExxonMobil has been leading an interna tional consortium of Japanese, Indian and Russian companies. ExxonMobil said it will not invest in new developments in Russia.TotalEnergies said it would ‘no longer provide capital for new projects in Russia’. Russian president Vladimir Putin has warned that Russia would seize the assets of international oil companies that no longer wanted to do business in Russia. ‘There are enough legal and market instruments for this,’ he said. Ben van Beurden, Shell CEO. ©AFP

PGS data shows potential in Campos Basin23 Shearwater wins 4D survey in North Sea26 Sercel deploys its nodes in Zambia30

Big international energy companies have signalled their intention to pull out of work ing in Russia after its invasion of Ukraine. Shell has announced its intention to exit its joint ventures with Gazprom and related entities, including its 27.5% stake in the Sakhalin-II liquefied natural gas facility, its 50% stake in the Salym Petroleum Devel opment and the Gydan energy venture. Shell also intends to end its involvement in the Nord Stream 2 pipeline project.

International energy companies pull out of Russia

‘Although it is too early to estimate the impact of international sanctions against Russia on oil demand, we can gain an insight by considering the demand realities from countries with recent expe rience of similar sanctions – Iran and Venezuela,’ said Rystad. ‘Oil demand dropped in these countries by a range of between 10% (Iran) and more than 30% (Venezuela), with the extreme case of a 50% drop between the peak and trough in Venezuelan demand from 2011 to 2019. A 10% to 30% drop in Russian demand would correspond to a total con traction of 350,000 to one million bpd in 2022. Rystad expects that half of that deceleration would be from industrial activities, while the rest would be driven by reduced internal mobility.

INDUSTRY NEWS 22 FIRST BREAK I VOLUME 40 I APRIL 2022

‘The economic fallout from the war –in addition to the humanitarian crisis – is going to be sweeping, both for Russia and Ukraine, and the region’s oil demand is going to take a severe hit if the conflict is prolonged and recently enacted sanctions remain in place,’ said Sofia Guidi Di Sante, oil market analyst with Rystad Energy.Total oil demand in Ukraine averaged around 260,000 bpd in 2019, with the road transport sector accounting for more than half of the total, at 138,000 bpd. Aviation demand is minimal, representing 5% of total consumption and estimated at 7000 bpd in 2019. If the war drags on and fighting con tinues, demand could fall by 50% or more, said Rystad. Such a drop in road and air traffic alone would shave off around 65,000 bpd of oil demand, which is 28% of expected monthly oil consumption for the country. In addition, disruptions in the supply chain and the impact on gross domestic product (GDP) growth would harm other sectors, leading to a potential additional drop in demand of 40,000 bpd. Russia is the sixth-largest oil con sumer globally, with oil demand totalling 3.6 million bpd in 2019, and a slow down in consumption would have severe domestic and international consequences, affecting global balances.

TGS launches wind data platform

War in Ukraine could result in as much as one million barrels per day (bpd) of oil demand being removed from the global market, Rystad Energy research shows. Oil demand in both Ukraine and Rus sia is set to plunge if an end to the conflict does not materialize quickly. Ukraine is likely to see the largest drop in relative terms, potentially losing more than 50% of demand so long as the war persists, with long-term implications inevitable due to infrastructure damage and the speed of getting facilities back online once the conflict has come to an end. Russia also stands to suffer signif icantly, although the impact in relative terms will be less, said Rystad. The direct and indirect sanctions imposed by the West on Russia’s financial system will reduce economic activity significantly, complicating the process for Russian com panies to conduct business internationally and for its citizens to travel abroad. That could result in an oil demand destruction of between 15% and 30% or more.

TGS has launched a wind data analytics platform that enables offshore wind market stakeholders to assess risks and opportu nities.Wind AXIOM is designed to offer interactive feasibility analysis by aggre gating many critical data categories in one place and subsequently enabling com prehensive benchmarking of current and future lease rounds. Jan Schoolmeesters, EVP of digital energy solutions at TGS, said, ‘In the devel opment of this easy-to-access platform, our mission was to improve the wind assess ment experience for everyone. TGS has leveraged 40 years of data expertise, includ ing that from subsidiary 4C Offshore, to help customers access multiple high-quality wind data resources in one place, screen offshore wind projects faster, and easily compare offshore wind lease opportunities across the globe. Wind AXIOM allows wind stakeholders to assess their potential investments and future opportunities.’ Wind AXIOM integrates and homog enizes a wide variety of data, said TGS. Data types include high-resolution wind resource data, energy assessment, the 4C offshore market, regulatory and policy intelligence, environmental and marine use restrictions, bathymetry data, transmission infrastructure, and other data sources. These are analysed together, providing early insights into the costs and risks of pursuing a particular lease area, the com pany added. Screenshot of the Wind AXIOM platform.

Ukraine war could cut global oil demand by one million barrels a day

PGS Brazil data shows potential in outboard Campos Basin

PGS Campos Deepwater GeoStreamer X MultiClient data with fast-track TTI RTM and depth velocity overlay illustrating potential subsalt and presalt exploration targets in the outboard Campos Basin.

The latest seismic depth data from PGS’ Campos Deepwater GeoStreamer X sur vey offshore Brazil gives new insight into the potential of emerging plays close to the recent high-impact Urissanê and Mairarê wells. The PSDM data illuminates explora tion opportunities in the outboard Campos Basin with PSDM products that cover open acreage blocks C-M-350, 417, 485, the company added. This is the only 3D data for open blocks in the upcoming permanent offer rounds. More than 10,000 km2 of open acreage outside the presalt polygon and more than 3000 km2 of acreage inside the polygon will be offered in the upcoming permanent offer‘Attentionrounds. has definitely returned to Campos, with encouraging announce ments of hydrocarbon shows in the recent Urissanê and Mairarê wells, the anticipation of the Marolo-1 well to the south, along with several other permitted wells in the area. This data indicates further potential in the basin,’ said John Cramer, Brazil area manager at PGS.Latest 3D TTI PSDM products cover open blocks in the outer Campos Basin, where new gravity and magnetic data are also available. The resolution of the grav ity/magnetic response has been optimized using the 3D data (covering 16,000 km2) and reprocessed publicly available 2D data for the northern Campos Basin area (~ 41 000 km2). This integrated set of geophysical prod ucts facilitates the assessment of seismic imaging for exploration risk mitigation and potential drilling hazard assessment, added PGS.Final multi-azimuth GeoStreamer X products due in August will complete the set. They will include TTI PSDM products for Blocks C-M-212, 279, 348, 350, 415, 417, 483, 485, 549. PGS will also provide Integrated 2D/3D gravity and magnetic data for regional basin analysis.

Meanwhile, the PGS vessel Ramform Titan has entered Galveston marking the first-ever visit of a Titan-class vessel to a US port. The PGS flagship vessel is mobilising for a 4D survey in the Gulf of Mexico.

Sophie Zurquiyah, CGG CEO.

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CGG reports fourth quarter net loss of $28 million CGG has reported a fourth quarter group net loss of $28 million on revenues of $471 million compared to a group net loss of $101 million on revenues of $217 mil lion in Q4 2020. The company reported an operating loss of $23 million compared to an oper ating loss of $60 million in Q4 2020. Net cash flow was $81 million. Geology, Geoscience and Reservoir revenue of $207 million was up from $176 million in Q4 2020, driven by a global increase in demand for high quality imaging of the subsurface especially in geologically complex basins, such as the Gulf of Mexico and Brazil. Multi-client revenue was $114 million, up 13% year-on-year. Prefunding revenue of multi-client projects was $59 million, down 160% year-on-year and the prefund ing rate was 158%. Multi-client after-sales were at $55 million this quarter, up 78% year-on-year.‘Themarket remains solid worldwide driven by our clients’ focus on near-field exploration, production optimization and increasing interest in new fields develop ment. During the fourth quarter CGG won a very large multi-year contract in Latin America for its Geovation seismic imaging software.Equipment revenue of $94 million compared to $108 million in Q4 2020. For the full year of 2021 net loss was $180 million on revenues of $941 million compared with a net loss of $437 million on revenues of $955 million in 2020. Sophie Zurquiyah, CGG CEO, said: ‘CGG delivered solid Q4 and 2021 results in line with expectations, confirming the gradual recovery trends that began earlier in the second half of the year across our businesses. We made significant progress towards our carbon neutrality objectives by reducing our scope 1 and scope 2 direct emissions in 2021 to respectively 2 and 43 kt eq.C02.‘Beyond our core businesses, CGG made substantial progress through 2021, organically growing to over 150 engineers focused on developing and offering a range of new technology and solutions to our traditional and new client base. Today these new businesses represent approximately 5% of group’s revenue, which provides a solid foundation for accelerated growth. As we continue to transform the CGG business profile into a technology company, we have the ambition to become a global leader in specialized digital sciences, energy transi tion technologies and services, and mon itoring and observation solutions. These new businesses are expected to generate above 20% of total revenue in 2025.’

Shearwater recycles four vessels

Shearwater GeoServices is recycling four seismic acquisition vessels Polar Mar quis, Oceanic Challenger, SW Emerald, and SW Eagle as part of its fleet renewal strategy.The first two vessels, Polar Marquis and Ocean Challenger, have been deliv ered in Turkey for recycling in accordance with EU regulations and the 2009 Hong Kong International Convention for the Safe and Environmentally Sound Recy cling of Ships. The other two vessels, which are not active, will be delivered for recycling later in 2022. The vessels were built between 1992 and 2000 and have not recently been commercially active. This is a continuation of Shear water’s commitment to fleet renew al, which includes the previously announced recycling of the Western Trident in 2021 and sale outside of the seismic industry of the CGG Alize 2020.

PGS has told markets that it is seeking new financing arrangements to main tain liquidity because of a ‘slower than assumed’ recovery of the seismic market. The company warned that as things stand it cannot repay loans that are matur ing this year. ‘As reported by the company on January 27, 2022, the seismic market recovery in 2021 has been slower than assumed in the debt rescheduling busi ness plan from 2020,’ said a company statement. ‘As a result, there is a risk that the company will not generate sufficient liquidity to repay the 2022 maturities whilst also meeting the other require ments of the main credit agreements, including the Minimum Consolidated Liquidity covenant. The company’s view on this challenge has not materially changed. It has started preparations for assessing alternative ways to address upcoming debt maturities, including engaging advisers to assist the company in thisMeanwhile,respect.’

Irene Waage Basili, CEO of Shear water, said. ‘Now, we have the youngest fleet of any major seismic company, with improved capacity, capability and effi ciency.’

PGS warns of liquidity problems

Magseis Fairfield makes Q4 net loss of $15 million Magseis Fairfield has reported a fourth quarter net loss of $15 million on revenues of $72.2 million. The company reported a gross profit of $21.6 million and an operating loss of $13 Full-yearmillion. 2021 revenue was $258.1 million with a gross margin of 28%. The backlog ended the year at $293 million, an increase of 48% year-on-year. Some $215 million of the backlog is for delivery in 2022 ($190 million in the first half of the year). New contracts are being secured at increasing margins, the company added. Magseis Fairfield predicts 25% overall market growth in 2022.Lower seasonal activity in the Gulf of Mexico was impacted by weather and environmental conditions, but the company completed data processing on Cornerstone MC project phase 1 and started a project in India. There were four new contract wins (plus an additional two contract wins since the end of the year) with ‘increasing margins’ but no late sales in Q4. Magseis Fairfield is holding £30 million in cash. ‘At a macro level we see contin ued tightness in the market with oil and gas inventories and OPEC+ spare capacity declining. Energy demand is expected to continue to grow in a post-covid new normal. We forecast that the OBN market will see dou ble-digit growth from 2022 onwards,’ said CEO Carel Hooijkaas in Magseis Fairfield.Onrenewables, the company is part of the Greensand CO2 storage consortium in Denmark. Engineering and project acquisition is scheduled for 2022. The company sees further opportunities in the US, Europe, and Asia.

PGS has invited share holder feedback on ESG issues.

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Irene Waage Basili, CEO of Shearwater. © Marit Hommedal.

Green Energy Group announces Q4 revenues of $10 million Green Energy Group (Seabird Explo ration) has announced fourth quarter 2021 revenues of $10 million, up from $1.9 million in Q4 2020. It reported an EBITDA loss of $1 million, compared to a $1.1 million EBITDA loss in Q4 2020. The company has reported ‘con tinued strong market outlook’ in both key battery metals and seismic servic es, including a key project initiated in marine minerals. It won an OBN source contract after quarter end, while a third party OBN source con tract has been cancelled. Meanwhile, it has received a letter of termination for a 12-month OBN survey. Green Energy Group has also launched a strategic review and the vessel Petrel Explorer has been put up for sale.

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TGS launches India data reprocessing project

TGS has launched its East Coast India seismic reprocessing project in support of the country’s licensing round sched ule. The project encompasses more than 250,000-line km of existing 2D data across an area of 500,000km2 offshore India’s east coast. TGS will utilize its proprietary 2D-cubed technology to cre ate a single, conformable, easily acces sibleThisdataset.new dataset offers coverage of the prospective Krishna-Godavari Basin and West Bengal Fan. The data uplift will allow explorers to develop structural and geological models in their pre-study evaluation process using a single con formable 3D 2D-cubedvolume.isatechnology from TGS for generating a 3D seismic migration volume from a set of 2D and 3D seismic lines. An advanced structurally con formable interpolation algorithm revi talizes existing 2D multi-vintage and 3D data. The volume can be used for both regional interpretation and the optimi zation of subsequent 3D and 2D survey designs.Will Ashby, EVP of Eastern Hem isphere at TGS, said: ‘TGS is pleased to be able to support the local energy industry to meet growing requirements by employing innovative processing techniques to maximize the poten tial of existing seismic data in the region.’East Coast India data will be made available to pre-funding companies dur ing Q1 2022.

The survey will take place0 120 km from the West Australian coast at Pardoo.

CGG wins approval for 3D survey offshore Australia

CGG has won approval to undertake the Sauropod three-dimensional (3D) marine seismic survey in Commonwealth waters of the Roebuck Basin, within explora tion permit WA-527-P offshore Western Australia. The purpose of the Sauropod 3D survey is to collect high-quality geo physical data about rock formations and structures beneath the seabed and assess potential for new oil and gas discoveries.3DOilpreviously had an environment plan (EP) accepted by Nopsema for this activity in July 2020. CGG is now plan ning to conduct and manage the survey in WA-527-P under a revised and updated EP. The Sauropod 3D survey will take a maximum of 60 days to acquire, and will be undertaken by May 2022. The precise timing of the survey is subject to vessel availability, weather conditions, environmental considerations and other operational considerations.

SW Cook will conduct the survey over six weeks during the summer season. Illustration. Source: Magseis Fairfield.

equipmentbuysFairfieldMagseisOBN

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Lundin has awarded Shearwater GeoSer vices a 4D ocean bottom seismic survey at the Edvard Grieg field in the North Sea.The vessels SW Cook and SW Tasman will conduct the six-week project during the summer season using its Qseabed crews. It will be the third survey that Shearwater has performed at the Edvard GiegPerfield.Eivind Dhelie, senior geophysi cist at Lundin, said: ‘The previous three surveys in 2016, 2018 and 2020 provided us with very high quality 4D images of the Edvard Grieg reservoir. These have been used to optimize the infill well locations on the field and supported an extended plateau production of approx imately five years as well as increased field reserves by more than 50 million barrels of oil equivalent. We have also made breakthroughs in reducing the turn around time for 4D processing to less than 10 days after last shot.’ Irene Waage Basili, CEO of Shear water, said: ‘During this project, we will test next-generation technology together with Lundin demonstrating our com mitment to delivering high-quality 4D images into the future.’

Shearwater wins 4D OBC survey in the North Sea

TGS reports fourth quarter net loss of $86 million TGS has reported a fourth quarter net loss of $86 million on revenues of $105 million compared to a net loss of $17 million on revenues of $143 million in Q4 2020. The company’s operating loss was $101 million compared to $25 million in Q4TGS2020.said its results included an impairment to its multi-client library of $97Operatingmillion. segment revenues of $119.5 million (compared to $120 mil lion in Q4 2020) included $25 million in prefuding revenues, $83 million in late sales and $11.5 million in proprietary‘Althoughrevenues.themulti-client market remains at a low level in a historical perspective, we have seen several positive signs of improvement lately, and the sales momentum in Q4 2021 was better than previous quarters. This is further underlined by the strong order inflow of more than $160 mil lion experienced during the quarter,’ said Kristian Johansen, CEO of TGS. ‘Our clients are currently experienc ing record high cash flow and have indicated significant E&P spending increases for 2022. Recent conversa tions with key customers indicate that this should impact seismic spending positively. The more positive market outlook along with our strong balance sheet, allow us to increase our mul ti-client investments for 2022.’ Free cash flow amounted to $55 million in Q4 2021, up from $28 million in Q4 2020. Cash balance was $215 million at the end of 2021 versus $196 million a year earlier.

Magseis Fairfield has acquired Carbon Transition’s proprietary node-on-arope handling systems. Magseis Fair field has paid an initial $0.5 million and has entered a profit-sharing model with the seller for surveys executed with this equipment over three years. ‘We see an increasingly optimistic outlook for a market recovery for OBN services in 2022 and beyond, and with this acquisition we are further con solidating the market with a minimal upfront payment. In a global envi ronment with significant supply chain delays this asset purchase gives us a time-to-market advantage to capture project opportunities. This acquisition adds to our delivery capability in the mid-water-depth market. The deal structure limits our financial risk and gives us the ability to deploy addi tional capacity quickly as the market continues to improve’, said CEO Carel Hooijkaas of Magseis Fairfield. The three-year payment model is conditional on the utilization of the equipment acquired. Earn-out pay ments are capped at $12 million and have a minimum payment of $1.5 mil lion, subject to certain milestones. The node handling systems Mag seis Fairfield acquires are currently installed on two Havila vessels with an additional system onshore and have previously been used for Carbon Tran sition’s large survey for ONGC in India and other Carbon Transition surveys in the Middle East and North Sea.

Schlumberger has launched the GeoSphere 360 3D reservoir mapping-while-drilling service. The service leverages advanced cloud and digital solutions to deliver realtime 3D profiling of reservoir objects, improving reservoir understanding and enhancing well placement to maximise returns from complex reservoirs.

Joe Blommaert, president of Exxon Mobil Low Carbon Solutions, said: ‘By expanding carbon capture and storage at LaBarge, we can reduce emissions from our operations and continue to demonstrate the large-scale capability for carbon capture and storage to address emissions from vital sectors of the global economy, including industrial manufac turing.’By capturing an additional 1.2 mil lion metric tonnes of CO2 each year, ExxonMobil can reduce to greenhouse gas emissions from its upstream operated emissions by 3%. The LaBarge facili ty currently captures nearly 20% of all human-made CO2 captured in the world each year, claimed ExxonMobil. Expansion ahead for ExxonMobil facility.

ExxonMobil has made a final $400 mil lion investment decision to expand carbon capture and storage at its LaBarge, Wyo ming,Atfacility.thefacility, which the compa ny claims has captured more CO2 than any other facility in the world to date, the expansion project will capture up to 1.2 million metric tonnes of CO2, in addition to the 6-7 million metric tonnes captured at LaBarge each year.

‘Unlike conventional technologies, 3D reservoir mapping while drilling identifies fluid bodies and faults, at a volumetric reservoir scale, which is unique in the industry,’ said Jesus Lamas, president, well construction. ‘This is a transforma tive digital capability that drives improved reservoir understanding, optimized well placement, increased reserves bookings and production per well, and enhanced field-development decision making. Our customers can place fewer, higher-quality wells with greater certainty and confi dence, improving returns from complex reservoirs and reducing the carbon inten sity of field Geomodellingdevelopment.’atthe reservoir scale delivers 3D characterization of structural, stratigraphic and lithographic features of the reservoir, which increases geosteering confidence, said Schlumberger. The Geo Sphere 360 service uses a combination of advanced cloud and computing solutions and digitally enabled hardware to acquire 3D electromagnetic data. This data is contextualised in real time to improve the understanding of resistive reservoir bodies and reservoir dynamics, contributing to better field development planning. The GeoSphere 360 service has under gone extensive field testing in various environments globally. In the Middle East, an operator leveraged the GeoSphere 360 service for real-time 3D mapping of sand channel bodies, resulting in optimal well placement and maximum reservoir exposure, said Schlumberger. In North America, an operator used the 3D res ervoir mapping-while-drilling service to characterise structural and stratigraphic features of a reservoir, providing seismic scale understanding that led to optimized field development planning. A North Sea operator used the GeoSphere 360 service to integrate data from multiple scales of measurements, enabling strategic geo steering decisions that helped to reduce uncertainties, maximise well placement and optimize production potential.

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ExxonMobil to spend $400 million on Wyoming carbon capture facility

GeoSphere has undergone extensive field testing in various environments globally.

Schlumberger delivers real-time 3D profiling of reservoirs while drilling

ExxonMobil completed front-end engineering and design work for the pro ject in December 2021 and was expected to issue the engineering, procurement and construction contract in March. Pending regulatory approvals, startup is estimated in 2025.

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Oil and gas briefs

TotalEnergies and APA Corporation have made a significant new oil and associated gas discovery at the Krabdagu-1 well, in the central area of Block 58, offshore Suriname. Located 18 km south-east of Sapakara South, Krabdagu-1 was drilled at a water depth of 780 m and encountered approx. 90 m of net oil pay in good quality Maastrichtian and Campanian reservoirs. TotalEnergies is the oper ator of Block 58, with a 50% working interest, while APA Corporation holds the remaining 50%. Equinor has won consent for exploration drilling in production licence PL 532 in the Norwegian Sea. Well 7220/8-3 and 7220/8-U-3 (pilot well) will be drilled to test a prospect named Skavl Stø. Water depth is 352 m. ConocoPhillips has won a drilling permit for well 6507/5-11 in production licence PL 891 in the Norwegian Sea. Equinor has won consent for exploration drilling in production licence PL 1049 in the North Sea. Well 34/9-1 S will be drilled to test a prospect named Cambozola. Water depth is 382 m. Aker BP and partners Cono coPhillips and Lundin have won approval of their plan for development and operation (PDO) for the Kobra East & Gekko (KEG) field in the Alvheim area in the North Sea. Total investments in the project are projected at around $1 billion and production is scheduled to start in the first quarter of 2024. Recoverable reserves in KEG are now estimated at around 50 million barrels of oil equivalents. Equinor has won a drilling per mit for well 7220/8-2 S in production licence PL 532 at the Johan Castberg field development in the Barents Sea. Licensees are Equinor (operator) 50%; Vår Energi 30% and Petoro 20%. Repsol has consent for life exten sion of the Blane field in the North Sea. The Blane field is part of production licence 143 BS, for which Repsol is the operator. This production licence was previously valid until the fourth quarter of 2022, but has now been extended to 8 July 2027. Blane produces from Paleocene sandstone. Equinor has won consent for exploration drilling in production licence PL 532 in the Norwegian Sea. Well 7220/8-3 and 7220/8-U-3 (pilot well) will be drilled to test a prospect named Skavl Stø. Water depth is 352 m. Shell is preparing to launch the sale of its stakes in two clusters of gas fields in the UK Southern Gas Basin. According to sources, Shell is looking to sell stakes in Clipper and Leman Alpha for up to $1 billion in total.

US wind sale offshore New York attracts $4.3 billion in winning bids

The US Department of the Interior has announced the results of the nation’s highest-grossing competitive offshore energy lease sale in history, including oil and gas lease sales, with the New York Bight offshore wind sale. The lease sale offered six lease areas totalling over 488,000 acres in the New York Bight for potential wind energy development and drew competitive win ning bids from six companies totalling approx. $4.37 billion A recent report indicates that the US growing offshore wind energy industry presents a $109 billion opportunity to businesses in the supply chain over the nextThedecade.provisional winners of the lease sale are: OW Ocean Winds East, which won the OCS-A 0537 with a $765 mil lion bid; Attentive Energy won lease area ocs-A 0538 with a bid of $795 million; Bight Wind Holdings won lease area OCS-A 0539 with a $1.1 billion bid; Atlantic Shores won lease area OCS-A 0541 with a $780 million bid; Inverener gy Wind Offshore won lease area OCA-A 0542 with a $645 million bid; and Mid-Atlantic Offshore Wind won leases area OCS-A 0544 with a $285 million bid.

ExxonMobil has started produc tion at Guyana’s second offshore oil development on the Stabroek Block, Liza Phase 2, bringing total production capacity to more than 340,000 barrels per day in only seven years since the country’s first discovery. Production from the Liza Unity vessel will reach 220,000 barrels of oil per day later this year. The Stabroek Block’s recoverable resource base is currently estimated at more than 10 billion oil-equivalent barrels.

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African natural gas output to double, says Rystad Untapped natural gas supplies in Sub-Sa haran Africa are set to be unleashed this decade, with output more than doubling from 1.3 million barrels of oil equivalent per day (boepd) in 2021 to 2.7 million boepd in 2030 due to vast undeveloped deepwater resources, Rystad Energy researchWhileshows.deepwater developments have played a crucial role in the region’s liquids output to date, averaging about 50% of annual production, gas output from such fields has been minimal. That is expected to change, however, as gas from deepwater reserves will surge in the coming years. Production from deepwater developments will skyrocket from 120,000 boepd in 2021, 9% of total output including shelf and land production, to 1 million boepd accounting for 38% of total output. As global demand for gas continues to rise and importing countries suffer supply headaches, the production outlook for the region is promising, said Rystad. Deepwa ter production is projected to grow further in the 2030s, with gas output more than doubling in five years to 2.1 million boepd by 2035. Gas from shelf and land reserves will increase by 2035 and will contribute about 46% of the expected 4 million boepd of total gas output from the region, based on estimated recoverable reserves, devel opment timelines and plans. Greenfield investments are also pro jected to soar. Gas and liquids greenfield capital expenditure in the region totalled $12 billion in 2021, with $8 billion spent on deepwater developments. By 2030, total greenfield investments will surge to almost $40 billion, of which $24 billion will go on deepwater projects.

‘The development of deepwater off shore resources is going to usher in a period of rapid growth for the region,’ said Siva Prasad, senior upstream analyst with Rystad Energy. Deepwater reservoirs tagged to TotalEnergies’ Area 4 LNG project in Mozambique, where trains 1 and 2 are expected to start production in 2028, hold an estimated 2.3 billion barrels of oil equivalent (boe) in gas reserves. South Africa’s Brulpadda field – also operat ed by TotalEnergies – holds 715 million boe, while the BP-operated Greater Tortue Ahmeyim floating liquefied natural gas (FLNG) development straddling the mari time boundary of Mauritania and Senegal has an estimated 300 million boe. Of the current potential recoverable reserves across Sub-Saharan Africa, about 60% lie in deepwater regions, of which close to 60% is gas. Mozambique dom inates with 52% of the total recoverable gas resources in the area, followed by the Senegal–Mauritania maritime region with a combined 20% and Tanzania with about 12%. Nigeria also holds significant recov erable reserves of gas that will contribute to the expected output hike. On the flip side, Sub-Saharan African liquids production is expected to drop below 4 million barrels per day (bpd) for the first time in more than 20 years but will recover by 2028 and return to 2020 levels of around 4.4 million bpd by the end of the decade. Liquids output is projected to grow in the 2030s, too, with total production of approximately 5 million bpd in 2035. About 40% of the total recoverable deepwater resources in the region are liquids, of which Nigeria accounts for 33% and Angola has 31%. Ghana and Mozambique are two other countries with significant untapped resources, amounting to 8% and 7%, respectively, of the region’s deepwater liquids reserves. However, Rystad warned: ‘Deepwater projects in Sub-Saharan Africa are risky and can be delayed or unsanctioned due to high development costs, challenges access ing financing, issues with fiscal regimes and other above-ground risks. With majors continuing to rein in upstream spending and plough a course on the energy transition to help lower emissions, many deepwater schemes will face challenges getting off the drawing‘Majorsboard.are, overall, focused on cut ting upstream costs, reducing emissions, increasing renewables and the energy tran sition, meaning such deepwater projects often have to take a backseat when it comes to apportioning investment. Euro pean banks are tightening regulations for funding high-emission hydrocarbon pro jects, and African banks could struggle to provide the necessary financing. This leaves Asian banks, mainly Chinese, with comparatively less strict regulations on funding fossil fuel developments.’

Ikon Science assesses energy storage caverns

Ikon Science is collaborating with Wood and Subsurface Dynamics (SSD) to eval uate pilot storage caverns. Wood has leveraged data consulting services from Ikon and SSD to provide due diligence, data review and validation for a multi-location A-CAES (Advanced Compressed Air Energy Storage) project involving Hydrostror, a firm using com pressed air in underground caverns to store excess electricity generated by wind farms. The data services provided by Ikon and SSD are helping to determine the viability of the subsurface conditions of Hydrostor’s proposed sites to support flexible energy storage. Ikon and SSD evaluated Hydros tor’s documentation, studies and reports to prepare a reliable risk assessment summary. Based on Ikon’s and SSD’s findings, Goldman Sachs Asset Man agement invested $250 million into Hydrostor’s A-CAES pilot project initiative.‘Accurately understanding the sub surface is fundamental to determining the feasibility of green energy storage projects,’ said Dr Denis Saussus, chief executive officer of Ikon Science. ‘As the world’s energy mix diversifies, assessing the subsurface remains piv otal to the success of renewable energy projects.’

Norway’s Ministry of Petroleum and Energy will now start work on designing an auction model for real ising phase one of the Southern North Sea II Thefield.Ministry of Petroleum and Energy will commission NVE to iden tify new areas for renewable offshore energy production based on input from an internal directorate-level commit tee and draw up a recommendation for an impact assessment programme. This work will take 9–12 months. Impact assessments will then need to be carried out before any new areas can be opened.

The programme is a collaboration between the Ministry of Mines of Zam bia, First Quantum Minerals and Oxford University’s Earth Sciences Depart ment. It is part of the UK Research and Innovation (UKRI) Copper Basin Exploration Science (CuBES) project to address the anticipated growth in demand for copper, cobalt and nickel as a result of the energy transition.

‘Interest in ultra-high-density 3D seismic is growing apace, driven by rapid growth in the market for offshore wind,’ said Matthew Kowalczyk, CEO of OFG.

‘With the addition of the P-Cable technology, OFG now provides the broadest range of marine geophysical data technology and services in the offshore market,’ said a statement from OFG, which is 43% owned by PGS.

The deal is expected to increase PGS’ shareholding in OFG up to approx. 55%. PGS will continue to work closely with OFG as a preferred supplier of ultra-high-resolution seismic data, controlled source electromagnetic data (CSEM), magnetic and acoustic surveying products and services in ener gy transition activities such as carbon storage, site investigations for offshore windfarms and mapping of seabed min erals for use in electrification.

2022Ocean Floor Geophysics buys NCS SubSea Ocean Floor Geophysics (OFG) has acquired the entire share capital in NCS SubSea, which owns and oper ates the P-Cable system providing ultra-high-resolution 3D seismic data.

Sercel deploys nodes in Zambia mining project

Emmanuelle Dubu, Sercel CEO, said: ‘Our participation confirms our opportunity for growth in the environ mental and alternative energy-related monitoring and observation markets ’

WiNG node used to explore the structure of a mine (image courtesy of Sercel).

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Sercel’s WiNG land acquisition nodes are making a key contribution to a big mining exploration programme in Zam bia’s Katangan copper-bearing basin. A 30 km-long WiNG node array is being deployed to acquire passive seismic data over a nine-month peri od across the Kansanshi mine owned by First Quantum Minerals and the adjacent Solwezi basement dome. The programme aims to explore the crus tal structure of the mine area using background seismicity alone (ambient noise, mine blasting, local and regional earthquakes and teleseismic events).

‘Our strategic collaboration with OFG and their acquisition of NCS Sub Sea further expands our offering within the New Energy markets. By bringing the ultra-high-resolution P-Cable 3D seismic technology into OFG, we can apply PGS’ inhouse data processing capabilities, expanding our offering for site characterization and shallow geo hazard applications,’ said Berit Osnes, EVP New Energy of PGS.

‘The multiphysics offering includes the widest range of sensor solutions deployed from surface, AUV and ROV platforms, and is combined with unique multiphysics processing, integration and interpretation know-how.

outlinesNorway wind energy plans Norway will implement phase one of wind power production in the South ern North Sea II area by allocating sea areas based on auctions. Phase one of Southern North Sea II will produce 1500 MW, or roughly 7 TWh per year – enough electricity to power 460 000 households. Phase two will produce another 1500 MW. A study by the Norwegian Water Resources and Energy Directo rate (NVE) in cooperation with Stat nett will determine how to connect the additional capacity to the grid.

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The initial focus of the group is a foundational carbon capture and storage (CCS) network to gather CO2 from more than 20 oil sands facilities in northern Alberta and transport it for safe storage in underground geological formations.Thealliance partners said their vision recognizes that oil is a significant source of greenhouse gas emissions that must be addressed as the world transitions to a lower-carbon future. At the same time, oil will continue to be needed for decades to come as part of a diversified energy mix – both as a transportation fuel and as a critical building block for products we use every ‘Thereday.isno switch to turn off hydro carbons and quickly ramp up renewables in a way that ensures a continued supply of reliable, affordable low-emissions energy,’ said Mark Little, president and CEO of Suncor. ‘All forms of energy will be required and by driving down our GHG emissions to net zero, Canada’s oil sands are well-positioned to help facilitate an orderly transition.’

Canada’s major oil sands producers are working together on a net-zero initiative that could ensure long-term supplies of responsible energy.

Canada oil sands producers form net zero alliance Canada’s big oil sands producers are working together on a net-zero energy initiative for North America. Canadian Natural, Cenovus Energy, ConocoPhillips Canada, Imperial, MEG Energy, and Suncor Energy have formed the Oil Sands Pathways to Net-Zero Alliance.Their aim is to achieve a phased reduction in emissions from oil sands operations, reaching net-zero by 2050, working in collaboration with Canadian federal and provincial governments. As the single largest oil resource on the continent, and the third-largest in the world, the Canadian oil sands can help to ensure long-term, secure supplies of affordable energy for Canada and the US, and for North America to become the preferred supplier of sustainable oil to the world, said the alliance. ‘The Pathways Alliance has a well-defined plan to reduce current oil sands emissions of 68 megatons per year in phases over the next three decades to ensure both near- and long-term pro gress,’ said Alex Pourbaix, president and CEO of Cenovus Energy. ‘By tackling our emissions challenge head-on, we’re working to ensure the oil sands can offer Canada, and the United States, a sustainable product and a higher degree of long-term energy stability and certainty,’ he added.

Canada has long been the number one supplier of imported oil to the US and is a significant and increasingly critical source of heavy oil feedstock for Gulf Coast and Midwest refineries. In 2020, Canada accounted for 52% of the nearly 7.9 million barrels per day of petroleum products imported into the US, far out pacing imports from other oil-producing nations.

Bell Geospace has processed 14,000 line km of airborne full tensor gravity gra diometry FTG and magnetic data in Sri Lanka.‘The new data products offer a much-improved understanding of this area’s geologic evolution and hydrocar bon potential,’ said John Macfarlane, executive vice-president of Bell Geo space. ‘The data quality is exceptional and holds the promise of new insights into exploration and results for Sri Lanka.’Key features of the data include an ability to construct quantitative crustal models of density and magnetic suscepti bility. This will scientifically improve the understanding of the geology in the region which in turn can predict hydrocarbon potential.Thedata complements the new flexi ble block maps and joint study agreements (JSA) implemented by the Petroleum Development Authority of Sri Lanka. The JSA previously was only available in the ultra-deepwater areas of Sri Lankan acre age but is now extended across all basins. The airborne data across blocks M1C1C2 were acquired in August 2021 and M2 were acquired in December 2021. The surveys were flown at a nominal clearance of 120 m above mean sea level (MSL) with a line spacing of 1 km and 5 km for tie lines.

Bell Geospace releases Sri Lanka airbone data

CGG has released a GeoVerse study to evaluate global geothermal energy potential and help to identify new sites and regions for future development. The study, which the company has made available for licensing, provides a base line dataset and analytical resource eval uation aid for explorers, operators and investors to discover, assess and compare opportunities.TheGeothermal Resource Assess ment study draws on CGG’s well, seismic and interpretation database and experience in more than 130 completed geothermal projects and applies a pro prietary methodology to evaluate more than 700,000 subsurface temperature dataCGG’spoints.

INDUSTRY NEWS 32 FIRST BREAK I VOLUME 40 I APRIL 2022

The UK’s Net Zero Technology Centre has launched its 2022 Open Innovation Programme aimed at developing technol ogies that will reduce offshore emissions, accelerate clean energy production, and enable delivery of the UK’s net zero ambitions.The2022 programme will feature two funding competitions, the first sixweek funding window opened on 16 March and the second is scheduled for October.

UK launches $10 million net zero technology competition

TGS can now provide access to well data from ~6500 wells located in Bra zil's offshore basins. TGS-enhanced data such as standardized digital logs (LAS, LAS+, Mud LAS, Lith LAS), validated well headers, quality-con trolled directional surveys and other available derivatives will be licensed through its cloud-based R360 Platform. Well data will further enhance geolog ical understanding of the area and enable E&P companies to maximize the potential for deepwater discoveries in one of the world's most prolific exploration basins, saidThisTGS.data will complement existing TGS 2D and 3D seismic coverage in addition to wide-ranging basin studies offshore Brazil and support operators in assessing prospectivity in blocks included in the Permanent Offer Round.

CGG delivers global geothermal resources study

Jan Schoolmeesters, executive vice-president of digital energy solutions at TGS, said: ‘TGS well data process ing will make it easier for customers to use and access this data, enhancing their ability to evaluate opportunities, acceler ating the exploration cycle, and reducing risk.’

Map of investigated locations for global geothermal resource potential including seismicity, basin, and geothermal power plants (image courtesy of CGG).

geothermal science experts investigated high-energy volcanic geo thermal systems as well as lower-tem perature but far more extensive systems associated with sedimentary basins that represent a significant emerging resource opportunity. The study and supporting primary data, delivered through the GeoVerse platform, allows subscribers to interrogate data in an interactive environment to address key geothermal system questions, said CGG.

TGS offers Brazil well data

Businesses from across the globe were eligible to apply for a share of £7 million available in the first competi tion, with a maximum of £1 million to be awarded to each successful project. The projects must support the transition towards net zero with an obligation of trialling and deploying technology within the UK continental shelf. As well as funding, the projects will also gain access to data, facilities, and technical expertise from industry. Seven technology focus areas have been identified for the first competition: carbon capture, utilisation and storage (CCUS); hydrogen and clean fuels; renewables and energy storage; zero emissions power; venting and flar ing; integrity management; and late life and Digitaldecommissioning.anddataarchitecture, smart assets and field automation will be includ ed in the technology focus areas within the second £3 million funding competition due for launch in October.

Other industries in the UK which cause tremors, such as geothermal, mining and construction face no such restrictions, it added.

Chevron shoots 4D survey offshore Western Australia

INDUSTRY NEWS FIRST BREAK I VOLUME 40 I APRIL 2022 33

Cuadrilla ordered to seal UK’s only two shale wells

The UK Oil & Gas Authority (OGA) has ordered Britain’s only two horizontal shale wells, operated by Cuadrilla, to be plugged and abandoned. Cuadrilla will permanently seal the two shale gas wells drilled at the Pres ton New Road (PNR) Lancashire shale exploration site despite concerns about the impact this will have on energy supply. It means the 37.6 trillion cubic metres located in the northern Bowland Shale gas formation will continue to sit unused, when just 10% of this volume could meet UK gas needs for 50 years. Instead, UK imports of Natural Gas are expected to skyrocket to more than 80% by 2050.Sources close to the UK government said talks were continuing on whether to reverse the decision in the light fresh concerns about energy supply after Rus sia’s invasion of Ukraine with the UK prime minister Boris Johnson promising a new energy strategy for Britain. Cuadrilla chief executive officer, Francis Egan, said: ‘At a time when the UK is spending billions of pounds annu ally importing gas from all corners of the globe, and gas prices for hard-pressed UK households are rocketing, the UK government has chosen this moment to ask us to plug and abandon the only two viable shale gas wells in Britain.

‘Cuadrilla has spent hundreds of mil lions of pounds establishing the viability of the Bowland Shale as a high-quality gas deposit. Shale gas from the North of England has the potential to meet the UK’s energy needs for decades to come. Once these wells are filled with cement and abandoned it will be incredibly costly and difficult to rectify this mistake at the PNR site. ‘What’s more ridiculous is that leav ing our own shale gas in the ground will make reducing global emissions even harder. Emissions from import ing gas are far higher than those from home-produced shale gas. I don’t think that this has been properly thought through.’InNovember 2019, the UK Govern ment announced a moratorium on shale gas Theextractiontwowells are the only horizontal wells drilled and hydraulically fractured into UK shale rock. The wells were drilled into the Bowland Shale to vertical depths of approx. 2.25 km and onwards horizontally for a further 0.75 km each through the Cuadrillashale.said that the site at Preston New Road has operated within the UK’s regulatory operating limit of halting operations if tremors no greater than 0.5 on the Richter Scale are recorded.

BRIEFS Baker Hughes has announced an invest ment in San Francisco-based GreenFire Energy Inc, an innovator in closed-loop geo thermal technology. Baker Hughes claimed that the combined offering will bring the first integrated Advanced Geothermal Systems (AGS) solution to the market, retrofitting both existing non-producing geothermal and oil and gas wells to closed loop heat producing wells for power generation and direct use applications. Getech has secured contract wins for its geoscience data and energy software prod ucts with a combined value of £1.2 million. The company’s customers will use these products to locate, de-risk and optimise the development, and long-term economic production of subsurface projects, including oil and gas, strategic minerals, geothermal, green hydrogen and carbon capture and Akerstorage.Carbon Capture and Northern Lights JV have signed a non-exclusive agreement to collaborate on carbon capture and storage (CCS) projects in Norway and across Europe. Together, the two companies represent a full value chain offering from carbon capture through to transport and storage. Chevron is looking to sell its stakes in three oil and gas fields in Equatorial Guinea, hoping a recent rally in energy prices will help to attract buyers. It acquired the assets in the west African country as part of the $13 billion acquisition of Noble Energy in 2020. The sale could raise as much as $1 billion. The Gambia has launched its 2022 Licensing Round for Block A1. The proposal deadline is 6 June 2022. Granted initially to BP in 2019, Block A1 became available in August 2021 after the company exited the block. During its time as licensee BP performed the required work obligations, including reprocessing 2D and 3D data, conducting geohazard, geology and geo physical studies, and progressed the block so that it is now drill ready. The 2D and 3D BP reprocessed data is available for licensing from TGS.

Chevron is shooting a big 4D marine seismic survey offshore Western Australia that is expected to take at least ten weeks to acquire.Thesurvey will cover produc tion licences WA-46-L, WA-47-L and WA-48-L in the Wheatstone and Iago gas fields in Commonwealth waters north of Barrow Island. The 4D project aims to repeat the acquisition of the 3D survey over the same area in 2011–2012, as part of a monitoring programme. The programme is scheduled to occur between mid-December 2022 and mid-April 2023, subject to vessel availability, and is expected to take ~75 days to Seismicacquire.acquisition will be conducted 24 hours a day. Chevron’s environment plan proposals have been published on the Nopsema website and are open for comment.

Sindre Knutsson, vice-president for gas and LNG market analysis at Rystad Energy.

INDUSTRY NEWS 34 FIRST BREAK I VOLUME 40 I APRIL 2022

LNG imports into Western Europe totalled 294 million m3 per day (MMcmd) in January 2022, a new all-time high uti lizing 100% of the region’s regasification capacity, with most additional volumes coming from the US. Of the total 8.6 Bcm of LNG that Western Europe imported in January, 56% or 4.8 Bcm came from the US, 1.7 Bcm came from Russia and 0.7 Bcm from Qatar. More LNG supply is available, but only if European countries are willing to pay elevated prices. The bulk of the extra LNG supply could come from the US, which has 102 Bcm of free on board (FOB) volumes on the market. Australia and Asia have most of the market’s available spot volumes, but those cargoes are unlikely to arrive in Europe due to long voyage distances. Instead, the US, Africa, parts of Europe and Russia’s Yamal LNG could offer additional spot LNG. Europe could also buy volumes from aggregators and traders looking to resell into the market.

‘Despite Europe’s implicit policy to reduce its dependence on Russian gas –as demonstrated by the significant buildup of LNG import facilities on Western Europe’s coast in recent years – Russia plays a pivotal role in helping meet the region’s gas needs,’ said Sindre Knuts son, vice-president for gas and LNG market analysis at Rystad Energy.

European gas storage levels remain historically low at 45 Bcm currently. This is 30% lower than the five-year average and amounts to only two months of gas to meet average winter demand. As a result, the region is particularly vulnerable to short-term movements in supply and demand, as evidenced by record spikes in traded gas prices on the Dutch Title Transfer Facility (TTF) in recent months. It also means any disruption to Russian gas flows via Ukraine into Europe would immediately impact traded prices, LNG import demand, and gas-to-coal switch ing for power generation, said Rystad. Western Europe (Northwest Europe, the UK and Scandinavia) imported 75 Bcm from Russia last year, accounting for 25% of total demand. Eastern Europe (the Baltic States, Central and Eastern Europe) imported 55 Bcm of Russian gas, equivalent to 57% of total demand, while Southern Europe (Iberia and the Mediter ranean countries) sourced 25 Bcm from Russia, equal to 21% of its total demand.

Neptune and RWE to develop green hydrogen in the North Sea Neptune Energy and RWE have signed an agreement to develop the offshore green hydrogen project ‘H2opZee’ ahead of 2030.H2opZee is a demonstration project which aims to build 300-500 megawatts (MW) electrolyser capacity in the North Sea to produce green hydrogen using offshore wind. The hydrogen will then be transported to land through an existing pipeline.Thepipeline has a capacity of 10-12 gigawatts (GW), so is already suitable for the further roll-out of green hydrogen production to gigawatt scale in the North Sea. The intention is to begin the feasibil ity study in the second quarter of 2022. H2opZee consists of two phases. In the first, a feasibility study will be carried out and an accessible knowledge platform will be set up. The objective is to start the roll-out of hydrogen at sea in the Netherlands. In the second phase, the project will be implemented. The scheme is supported by the Dutch government. H2opZee will add up to 500MW of electrolyser capacity.

War in Ukraine could lead to European gas supply crisis, warns Rystad War in Ukraine could put up to 155 bil lion m3 per year of natural gas imports to Europe at risk, if the conflict causes Russia to halt deliveries, Rystad Ener gy research estimates. The figure cor responds to 30% of Western Europe’s annual gas demand. If Russian exports were shut off entirely, Europe would struggle to meet its gas needs. Eastern Europe would be most severely hit as the region is the most reliant on Russian imports, whereas Western Europe could, in theory, fill the void with increased LNG imports, primarily from the US. Western Euro pean countries have nearly enough LNG import capacity to replace all Russian gas but would need an additional 8 Bcm of domestic production to make up the difference to 2021 levels. Of the 155 Bcm of piped gas Europe imported from Russia in 2021, 40 Bcm was piped through Ukraine. If only the 40 Bcm were taken off the table, Europe could make up the difference with rela tive ease, but would have to pay higher spot prices for the replacement volumes.

Meanwhile, interest in passive seismic techniques, particularly microseismic monitoring, is continuing to grow, driven by the success of such techniques for providing insights into subsurface geomechanical processes. The ability to record low frequencies has become more effective as technology continues to improve and has helped to drive greater interest in ocean bottom seismic nodes for permanent reservoir monitoring. The technique also lends itself to monitoring of potential CO2 storage reservoirs that will be required during the energy transition.

Large-scale exploration of shale oil and gas in America has driven innovation in the seismic characterization of unconventional reservoirs. Now that the energy sector is recovering from the pandemic the onus is back on the industry to innovate as unconventional reservoirs become viable again. The latest methods to predict the performance of multi-fractured horizontal wells will be showcased.

Ruud Weijermars reports on lessons learnt from geothermal pilot projects using hydrocarbon wells paired with insights from commercially operated geothermal power plants. PASSIVE SEISMIC

Special UNCONVENTIONALSTopic AND

Submit an article First Break Special Topics are covered by a mix of original articles dealing with case studies and the latest technology. Contributions to a Special Topic in First Break can be sent directly to the editorial office (firstbreak@eage.org). Submissions will be considered for publication by the editor. It is also possible to submit a Technical Article to First Break. Technical Articles are subject to a peer review process and should be submitted via EAGE’s ScholarOne Youhttp://mc.manuscriptcentral.com/fbwebsite:canfindthe First Break author guidelines online at www.firstbreak.org/guidelines. 48 FIRST BREAK I VOLUME 40 I MARCH 2022 Special Topic overview January Land Seismic February Digitalization / Machine Learning March Reservoir Monitoring April Unconventionals and Passive Seismic May Global Exploration Hotspots June Leading Geosciences in a New Era July Modelling / Interpretation August Near Surface Geo & Mining September Reservoir Engineering & Geoscience October Energy Transition November Marine Acquisition December Data Management and Processing More Special Topics may be added during the course of the year.

Simone Re et al present a feasibility study investigating the adoption of multiple DAS systems installed in wells for seismological monitoring purposes.

Paul A. Nyffenegger et al demonstrate the promising performance of permanently deployed, networked SADAR arrays to detect and locate microseismicity associated with CO2 storage reservoirs.

Isaac Easow highlights key formation evaluation technqiues that have helped operators to complete wells.

Randy Hickman et al demonstrate why 3D geomechanics models provide subsurface stresses which are more relevant when estimating fracture extent and can be used for interpretation of potential stimulated rock volume (SRV).

FEATURE: MINUS CO2 CHALLENGE FIRST BREAK I VOLUME 40 I APRIL 2022 81

Figure 1 Global prospectivity geological storage of CO2 (IPCC,2005; Bradshaw and Dance, 2005). Indian Institute of Technology | 2 Federal University of Bahia | 3 Khalifa University of Science and Technology University of Stavanger | 5 Dalhousie University

The best four teams were selected to present their work to the jury by video conference and after a close-run discussion placed: (1) Indian Institute of Technology (IIT; Bombay, India), (2) Federal University of Bahia (UFBA; Bahia, Brazil), (3) Khalifa University of Science and Technology (KUST; Abu Dhabi, United Arab Emir ates), and (4) University of Stavanger (UiS; Stavanger, Norway).

Congratulations to the finalists, and all the teams that participated. This article presents a summary of the results, highlighting the leading contributions of each of the finalists, with comparison to storage estimates by the organizers, and comparison to analogue offshore basins in the USA, Norway, and UK (via online carbon storage atlases). It is, to our knowledge, the first comprehensive quantitative assessment of storage capacity on the margin to be published. And, although by nature a competition, we emphasize the value of multiple independent ideas followed by, in effect, peer review and collaboration. Carbon storage potential offshore Atlantic Canada (Figure 1) was recognized by Bachu (2003) and in the 2005 IPCC Special Report on Carbon Storage based on work by Bradshaw and Dance (2005). In 2010, Pothier, Wach and Zentilli systematically assessed reservoir-seal pairs in the region, identifying significant injectiv ity, storage and containment potential on the Scotian Shelf, but expressed reservations about porosity and permeability in Paleozoic basins onshore, consistent with an exploratory well drilled by an industry, government, university consortium in 2014 (the CCS1 well in Cape Breton: OERA, 2017). Deep-water exploration on the Scotian Slope has yet to reveal extensive reservoir/aquifer development (OERA, 2011 & 2019) but extensive salt diapirism presents an additional opportunity, recognized by the UiS team, at the experimental frontier of carbon storage (e.g.: da Costa et al., 2020). This observation also leads to consideration of a few diapirs on the shelf. Caverns in older salt formations onshore Nova Scotia have been used for methane storage and considered for compressed air storage in an area with existing (and high potential) wind, tide, and pipeline infrastructure (Dusseault, Bachu and Rothenberg, 2004; Dusseault and Wach, 2020). A $75 million methane storage project at Alton demonstrated the principle but has recently been discontinued for commercial reasons (Henderson, October 2021).

* Corresponding author, E-mail: billrichards888@hotmail.com

1

4

Based on this, they have developed strategies for carbon neutrality in the region by 2050. In total, nine teams received a dataset assembled by Dalhousie University to develop their ideas. For competition pur poses, well log data were made available by Divestco, and regional NovaSPAN seismic data by ION. Key references and websites were provided and are listed here, with some additions.

Arpita Chakraborty1, Matheus Radamés Silva Barbosa2, Ahmed Samir Muhammad Rizk3, Kyle Watts 4, Bill Richards 5* and Grant Wach 5

Introduction In the third edition of the Minus CO2 Challenge, the EAGE invited multidisciplinary teams of university students to present their assessment of carbon storage potential in deep saline aquifers and depleted hydrocarbon fields offshore Nova Scotia, Eastern Canada.

Minus CO2 Challenge 2021/2022 – Student teams evaluate potential world-class carbon storage capacity offshore Nova Scotia, Eastern Canada

FEATURE: MINUS CO2 CHALLENGE 82 FIRST BREAK I VOLUME 40 I APRIL 2022

Figure 3 Perspective view of the Scotian Margin showing the Abenaki-Roseway Carbonate Bank, the Sable Island Delta, and key post-rift litho-stratigraphic formations. Based on OERA, 2011 (after J. Wade, modified Grant,1986, CNSOPB,2009).

Figure 4 Depleted gas and oil fields (red: Deep Panuke and Sable Gas Project; Green: CoPan). stranded gas fields (orange). Project wells = large dots; other wells = small dots. A-A’ = location of crosssection in Figure 5.

The teams were first asked to estimate storage potential in deep saline aquifers on the shelf, within an extensive (~700 km by ~150 km) monoclinal wedge of Middle Jurassic to Late Cretaceous sediments that subcrop seabed glacial deposits approaching the

Figure 2 Nova Scotia Margin showing the project area on the Scotian Shelf, the 200 m isobath (shelf-to-slope), the Abenaki Carbonate Bank (Kidston et al., 2007) and the Sable Island Delta (Kendell and Deptuck, 2012).

coast of Nova Scotia Figures 2, 3 and 4). These post-rift sediments were deposited as successive mixed siliciclastic-carbonate systems on a classic low-latitude passive margin. High porosity-per meability aquifers are focused at the seaward margin of the Bajocian-Barremian Abenaki-Roseway Carbonate Bank (Abenaki and Missisauga Formations), in intercalated paralic silici-clastics sourced from Nova Scotia (Mohawk, MicMac and Lower Missi sauga Formations), and in the Kimmeridgian-Cenomanian Sable Island Delta (MicMac, Missisauga and Logan Canyon Formations) that progressively interfingered with and overwhelmed preceding systems, sourced from the Avalon uplift to the north, in Labrador and Newfoundland. These forestepping systems each exceed 1500 m thickness at their respective shelf-edges (Figures 5 and 6) where they transition to hemipelagic muds, marls, and silts on the slope. They are capped by low permeability Late Cretaceous and Ceno zoic mudstones (e.g.: the Dawson Canyon Formation) and marls/ chalks (e.g.: the Wyandot Formation) which provide a regional topseal. There are many intra-formational seals, some of which are regionally extensive, notably the ‘O’ Marker (a succession of low permeability, diachronous, shelfal oolitic limestones at the top of the Middle Missisauga Formation) and the Naskapi Shale (the lowest member of the Logan Canyon Formation) which provides topseal in six fields. Teams estimated reservoir/aquifer properties from digital logs in 40 wells calibrated by core data (representative of 207 wells on the margin) and then derived gross rock volumes and net pore volumes in three zones using four regional structural Carbon storage potential – deep saline aquifers on the Scotian shelf

Middle Missisauga (K125-J150) and the Abenaki with its coeval Mohawk, MicMac and Lower Missisauga clastics (J150-J163). Storage capacity in deep saline aquifers was then estimated using storage efficiencies in the 1-8% range (based on analogues and numerical models, notably in online Norwegian and American carbon storage atlases: NPD, 2019; US DOE 2010 & 15; Vidas et al., 2014). The density of supercritical CO2 used in calculations was typically ~0.7 gm/cc. horizons provided by the organizers (as ASCII files and in a Petrel framework – courtesy Schlumberger). The structural model was built by the organizers from online digital data in the Nova Scotia Play Fairway Analysis (K94, K130, J150 and J163 horizons; OERA, 2011) and extended landward to the regional onlaps and subcrops using the Geological Survey of Canada atlas of the margin (Cant,1991). Three zones were layered for properties: Logan Canyon (K94-K125), Upper and Scotian Shelf - Deep Saline Aquifers (Effective Storage) Gt CO2 Gt CO2 Gt CO2 Min. - Base Case - Max. 7 151 1280 KUST: P90 - P50 - P10 99 658 1472 Mean and Max. Storage Efficiency = 50%, 75%, 100% 0,147 0,221 0,295 KUST: 0,336 IIT: 0,319 UFBA: 0,248 Analogues - Depleted Fields (Effective Storage) Gt CO2 Gt CO2 Gt CO2

USA Gulf of Mexico: Low Avg. High (Vidas, 2012) 15 UK North Sea and Irish Sea: P50 (Bentham, 2014) 8 Norway North Sea: Summary (NPD, 2019) 13 Table 1 Estimates of effective CO2 storage capacity on the Scotian Shelf with comparison to analogue basins.

FEATURE: MINUS CO2 CHALLENGE FIRST BREAK I VOLUME 40 I APRIL 2022 83

Organizers:

IIT:

215 648 Analogues - Deep Saline Aquifers (Effective Storage) Gt CO2 Gt CO2 Gt CO2 USA Gulf of Mexico: Low Avg. High (Vidas, 2012) 429 3198 5967 USA Offshore Carolinas: Low Avg. High (Vidas, 2012) 47 317 587 UK North Sea and Irish Sea: P50 (Bentham, 2014) 67 Norway North Sea: Summary (NPD, 2019) 46 Scotian Shelf - Depleted and Stranded Fields (Effective Storage) Gt CO2 Gt CO2 Gt CO2 Organizers:

Figure 5 Well log cross section A-A’ datumed on K94. Location Figure 4. Left track: Vshale (0-1) with lithology from cuttings (Fensome, OERA, 2011, where available). Yellow=sand, orange=silt, grey/ brown=mudstone, blue=marl, chalk, limestone. Centre track: True vertical depth subsea. Right track: Red=sonic porosity (0-50%): Hunt Gardner Rayner with Vshale cutoff and 10% porosity cutoff (+30% cutoff in model). Blue dots= core porosities 0-50% (OERA, 2011). Horizons are based on K94, K130, J150 and J163 surfaces from OETR (2011), and are used to define 3 zones: Logan Canyon, U. & M. Missisauga, L. Missisauga / Mohawk / MicMac / Abenaki.

On the other hand, a massive, unconfined, system of hydro-pressured aquifers (extensively interbedded with low per meability mud and marlstones) is likely to enhance dispersal of injected CO2 (and residual trapping), reduces the risk of pressure build up and geomechanical failure (IIT team), and is favourable for injectivity at wells (IIT team). Detailed modelling, incorpo rating sand-filled distributary and estuarine channel systems is needed to refine migration pathways modelled by O’Connor et al. in 2019 (which used coarse sub-regional grids and a default relative permeability curve). Carbon storage potential — depleted and stranded fields

Compared to storage estimates in similar areas of the North Sea (45 GtCO2, Norwegian Petroleum Directorate Atlas; 70 GtCO2, CO2STOR in the UK, Bentham et al, 2014) Scotian Shelf estimates are somewhat higher, probably because of the large sediment sup ply with less structural-stratigraphic complexity (apart from a few shallow salt diapirs – which present a risk of leakage (O’Connor et al., 2019) – and local, deep, overpressured depocentres controlled by shelf-margin listric growth-faulting). Aquifer quality improves updip in these sand-rich fluvio-deltaic-estuarine systems and with out large traps this results in a comparatively small hydrocarbon endowment with relatively small storage potential in depleted and stranded fields (Table 2: base case storage estimates).

ment of core data high-graded the Upper Missisauga Formation (below the Naskapi Shale). A random forest model led to well log permeability prediction. Joint seismic data and isopach map analysis led to calculating an injectable mass of 42 MtCO2 in the sub-volume considered. UiS assessed four sub-regions, two on the shelf and two on the slope with theoretical storage capacity (the physical limit the geological system can accept: IEAGHG, 2009) between 890 and 1498 Gt CO2 (equivalent to effective capacity of 45-75 Gt CO2 with a 5% efficiency factor).

Carbon storage potential – comparison to deep saline aquifers in analogue basins

Using a Monte Carlo simulation the KUST team estimated P90, P50, and P10 storage capacities at 99, 658 and 1472 GtCO2 Similarly, the IIT team estimated a mean of 215 and a maximum of 648 GtCO2 via a probabilistic model. These storage estimates for the shelf as a whole (Table 1) compare reasonably to a base case of 151 GtCO2 by the organizers that was derived by propagating sonic porosities (with cutoffs) throughout the Petrel framework and applying a base case storage efficiency of 3% and a depth interval of -800 to -4000m. A transect through the porosity model and porosity-thickness maps are shown in Figure 6. Bracketing sensitivities ranging from 7 to 1280 GtCO2 were derived using storage efficiencies of 1-8%, depth intervals that ranged from 800-3000 m subsea to 800-5000 m subsea and by varying average net-to-gross and porosity. Based on an analysis by Kearns et.al (2017) a wide range of scoping estimates between workers is not unusual: USGS and US DOE estimates of storage capacity in the USA are consistent at the low end, but medium estimates vary by a factor of 2 and at the high end by a factor of nearly 4. The UFBA team used an innovative machine learning approach to assess a specific aquifer within a sub-area. Seismic clustering was used for seismic horizon picking. Statistical treat

Five gas fields within the Sable Island Delta (rollover anticlines above shelf-margin, down-to-basin, listric faults) were developed and produced between 1998 and 2018 in the Sable Gas Project (cumulative production 2.1 TCF) and were decommissioned leaving an abandoned offshore pipeline that was connected to the onshore Maritimes and Northeast pipeline (Figure 2). Also, within the delta, two small oilfields (CoPan Project) produced 44.5 MBO between 1992 and 1999 from low-relief drapes above the downdip raised-rim of the Abenaki Carbonate Bank. The bank itself produced 147 BCF of gas between 2013 and 2018 (Deep Panuke project) from a structural-stratigraphic-diagenetic trap within its hydrothermally altered downdip seaward margin. About 2 TCF of gas resources remain undeveloped, mainly in

Figure 6 Three-zone porosity model of the Scotian Shelf. Vshale and lithology logs are shown on the transect. Porosity-meters of aquifer are shown for the Logan Canyon zone, upper and middle Missisauga zone and the Lower Missisauga, Mohawk, MicMac, Abenaki zone. The influx and waning of the Sable Island Delta from the NNE is apparent.

FEATURE: MINUS CO2 CHALLENGE 84 FIRST BREAK I VOLUME 40 I APRIL 2022

Compared to offshore basins in the US (Vidas et al., 2012), Scotian Shelf estimates are similar to the Atlantic margin off the Carolinas (Low, Average, High: 47,317,587 GtCO2) but, unsurprisingly, smaller than the Gulf of Mexico (429, 3198, 5967 GtCO2). The Atlantic margin off New Jersey is not assessed but probably has similar potential to offshore Nova Scotia.

South Venture field simulation

UFBA 248 MtCO2. This compares to much larger published esti mates in North Sea fields (13 GtCO2 Norway; 8 GtCO2 UK) and a surprisingly low estimate in the Gulf of Mexico (15 GtCO2).

The teams were provided with a static model of South Venture Field and, if simulation software were available (courte sy Schlumberger), were asked to history match production (~ 315 BCF) followed by injection of CO2 to identify when injected CO2 would spill outside structural closure (providing an estimate of storage efficiency within the trap – if that is a concern, bearing in mind that residual trapping in deep saline aquifers is widely considered adequate without a conventional hydrocarbon trap).The UiS team achieved good history matches to production, as did the University of Manchester and Heriot Watt University who were not among the finalists. Assessing leakage outside spill was more difficult, requiring assessment of cross-fault reservoir juxtapositions at the north bounding rollover anticlines similar to the Sable fields. The location of these fields is shown in Figure 4 and base case storage capacity in each field is summarized in Table 2. Teams assessed carbon storage potential in the depleted and stranded fields (as if they had been produced) via material balance from cumulative production and P50 resources published online by the Canada Nova Scotia Offshore Petroleum Board (Smith et al., 2014). PVT data and formation volume factors are available online in field development plans lodged by the opera tors, and the above report. Carbon storage based on reservoir pore volumes calculated from produced (or producible) hydrocarbons was typically estimated with a storage efficiency of 75% based on the IEA GHG 2009 Technical Study ‘CO2 Storage in Depleted GasTheFields’.results were quite consistent (Table 1). Totalling all fields, the organizers estimated low, medium, and high cases of 147, 221 and 295 MtCO2 (evenly split between depleted and stranded fields); KUST estimated 336 MtCO2, IIT

FEATURE: MINUS CO2 CHALLENGE FIRST BREAK I VOLUME 40 I APRIL 2022 85

319 MtCO2, Depleted fields CNSOPB published cumulative production Estimated weighted FVF (Estimated from Dev. Plans) CO2 Storage Density=0.7 E= 75% BCF / MB0 103 sm3 sm3 /rm3 Mt CO2 S.Venture 314.6 8,908,194 285.0 16.4 Venture 493.6 13,977,451 350.0 21.0 North Triumph 292.2 8,273,692 300.0 14.5 Alma 516.0 14,612,931 250.0 30.7 Thebaud 501.3 14,194,298 360.0 20.7 Sub-Total 2117.7 59,966,566 103.2 Deep Panuke 147.3 4,170,559 400.0 5.5 CoPan 44.5 7,066,810 0.8 4.6 Total 2264.9 131,170,500 113.4 Stranded Gas Fields (if depleted) CNSOPB SDL Report (2014) P50 Resources Estimated weighted FVF (Estimated from report) CO2 Storage Density=0.7 E= 75% BCF 10^9 M3 sm3/rm3 Mt CO2 Arcadia 158 4.5 400 5.9 Banquereau 170 4.8 280 9.0 Chebucto 66 1.9 275 3.6 Citnalta 172 4.9 290 8.8 Glenelg 508 14.4 270 28.0 Intrepid 54 1.5 260 3.1 Olympia 143 4.1 350 6.1 Onondaga 304 8.6 250 18.1 Primrose 127 3.6 160 11.8 South Sable 8 0.2 265 0.4 Uniacke 20 0.6 405 0.7 West Olympia 30 0.8 330 1.4 West Sable 93 2.6 170 8.1 West Venture C-62 31 0.9 375 1.2 West Venture N-91 68 1.9 385 2.6 Total 1952.0 55.3 108.8 Table 2 Base camp storage capacity in depleted and stranded fields (if produced).

FEATURE: MINUS CO2 CHALLENGE 86 FIRST BREAK I VOLUME 40 I APRIL 2022

Figure 7 Power Plants with 150 km radii. Well log X section – TVDss. J150 (blue), K125 (red), K94 (green) at -800 m risk of leak up to base Dawson Canyon above -800 m and free gas migrating to subcrop

Strategic plans Given the considerable storage potential of the Scotian Shelf (probably multiple times annual global emissions of ~36 GtCO2 in 2021) and relatively low carbon emissions in the province, carbon neutrality in Nova Scotia is eminently feasible even if all provincial emissions were stored offshore. If costs, credits, and commercial drivers are compelling, the questions are how to select, optimize and phase storage locations; how to integrate this with onshore infrastructure in the so-called ‘Energy Corridor’ (Dusseault and Wach, 2020); and how the upside potential of the offshore storage resource might be captured, considering carbon delivery and credits from northeastern North America and sea borne delivery and credits from Europe. It is possible at this scale that a large commercial offshore industry could be developed that avoids the environmental and safety concerns that are common in inhabited areas onshore. The teams focused offshore, with UiS presenting the most creative phased approach. Phase 1 would focus on CO2 injection into depleted fields (with 4D seismic monitoring similar to Sleipner Field, Norway as suggested by multiple teams) as well exploring the installation of a hydrogen storage facility. Phase 2 fault of the field. Injecting 1 MtCO2/year (similar to Sleipner or Snohvit, offshore Norway) into seven low-relief reservoirs, the organizer’s simulation shows minor migration of CO2 outside structural closure beginning early in the simulation (dependent on injection rate). Economic models

The teams took fairly consistent approaches to screening economic models using published ranges of costs (e.g.: Leung et.al., 2014) and a Nova Scotia carbon price that increases by C$15/year to C$170/tonne in 2030 (e.g.: Gorman, 2022). UFBA modelled 7 MtCO2/year of storage (similar to emissions from Nova Scotia power plants, Figure 7). The KUST team modelled 12 MtCO2/ year similar to 13.2 MtCO2/year of emissions from Nova Scotia and New Brunswick power plants and refineries (CER – Canada Energy Regulator, 2017). If other measures were not in place, and it was required, 12 MtCO2/year could dispose of about 75% of total Nova Scotia emissions in 2019 (16 MtCO2: Government of Canada, 2021). The KUST team presented a straightforward undiscounted model (Table 3), considering storage of 12 MtCO2/year for 30 years which we present here as a basic template for discussion. We then use cost sensitivities from the UFBA team report and a range of potential carbon credits. Costs are commercially sensitive and can be difficult to estimate so we have compared the teams’ costs to published benchmarks. Carbon capture is the biggest hurdle. In Table 3 the cost of upgrading (mainly coal) power stations ranges from $7-13 billion which is ~$1-1.5 billion per plant if eight power stations and refineries are considered. Upgrades at the Boundary Lake project in Saskatchewan achieve 1 MtCO2/year cost US$1.5 billion in 2014 (MIT, 2016). Costs in a new project in Nova Scotia would probably be higher on a one-off basis but might be similar allowing for economies of scale and technological improvements. Costs of transport, storage, and monitoring ($3-9 billion) can be broadly compared to the Sable Gas Project which ‘reported spending C$2.8 billion ($2.2 billion) in Nova Scotia, (and) C$1.9 billion (US$1.5 billion), in royalties to the provincial government” (Jaremko, 2018). The expenditures at Sable involved 22 wells, five production platforms, a compression platform and 340 km of pipelines (Jaremko, 2018) plus onshore gas and fractionation plants. A 12 MtCO2/year storage project would probably involve about 17 wells based on a 0.7 MtCO2/year/ well model considered in

Ringrose and Meckel’s 2019 analysis of the global effort to meet 2DS emissions reductions (two-degree scenario). These wells are likely to be closer to land than the Sable wells unless synergies with stranded fields are considered (as suggested by a number of teams): for revenue, to drive compression, for enhanced recovery (IIT) possibly to prevent early water breakthrough in low relief fields. KUST suggested offshore wind power to generate compression and UiS suggested generation and storage of hydrogen in salt diapirs. In addition, engineering might be more cost effective than a Sable vintage project with increased use of subsea tie backs. With these considerations, the costs of transport and storage in Table 3, US$ 3-9 billion, might not be unreasonable at the higher end. Storage of 12 MtCO2/year in Table 3 incurs base case costs of $US19.4 billion with a prize of $US21.6 billion over 30 years with carbon credits of US$60/tonne – an undiscounted profit of over $US2 billion. Applying a range of costs from the UFBA report and carbon credits up to $US150/tonne, undiscounted profits range up to US$54billion. If suitable incentives can be guaranteed, and costs can be managed, this could be a significant commercial opportunity for corporations with the capital and expertise to execute this type of project.

A further consideration is pore pressure in deep saline aquifers. Inboard of successive forestepping shelf-margins the monoclinal delta is dominantly normally pressured at prospective storage depths (as is the Abenaki Carbonate Bank) but at the deltaic shelf-margins, overpressures in confined growth-fault controlled depocentres (‘expansion trends’: Pe-Piper and Piper, would implement hydrogen storage in salt caverns, with further evaluation of deep saline aquifers in Phase 3, which would then be implemented in Phase 4 – probably in the Upper and Middle Missisauga Formations. Several teams – including UiS, KUST & UFBA — identified the Missisauga Formation specifically as the most promising of the deep saline aquifers (ultimately resulting from its deposition when the Sable Island Delta was most prolific) but there is room for considerable research evaluating which of the major formations is most suitable. This would require balancing storage capacity and injectivity as functions of porosity, permeability, and net thickness with pipeline distance offshore (Figure 7) and depth of burial. The 800 m subsea contour at the top of each of the major stratigraphic intervals is shown in Figure 7. With the exception of the Abenaki Carbonate Bank, reservoirs/aquifers become shallower, less compacted, more proximal, and better quality, landward. However, intraformational and sub-regional Depleted fields CNSOPB published cumulative production Estimated weighted FVF (Estimated from Dev. Plans) CO2 Density=0.7StorageE=75%

BCF / MB0 10 3 sm3 sm 3 /rm 3 Mt CO2 S.Venture 314,6 8.908.194 285,0 16,4 Venture 493,6 13.977.451 350,0 21,0 North Triumph 292,2 8.273.692 300,0 14,5 Alma

seals are less well-developed in this direction introducing con tainment concerns. Evaluating the relative merits of the key formations should involve dynamic modelling with much finer grids and more detailed stratigraphic architecture, considering different styles of channel systems and intervening non-reservoirs that enhance dispersal, residual trapping and dissolution of CO2: massive inter-cutting fluvio-deltaic distributaries in the Missisauga Formation; cyclical shallow marine parasequences with abundant, relatively thin, sand-filled estuarine channels in the Logan Canyon Formation – both evident on 3D seismic data (e.g.: Kendell and Deptuck, 2012; OERA, 2011).

FEATURE: MINUS CO2 CHALLENGE FIRST BREAK I VOLUME 40 I APRIL 2022 87

516,0 14.612.931 250,0 30,7 Thebaud 501,3 14.194.298 360,0 20,7 Sub-Total 2117,7 59.966.566 103,2 Deep Panuke 147,3 4.170.559 400,0 5,5 CoPan 44,5 7.066.810 0,8 4,6 Total 2264,9 131.170.500 113,4 Stranded Gas Fields (if depleted) CNSOPB SDL Report (2014) P50 Resources Estimated weighted FVF (Estimated from report) CO2 Storage Density=0.7 E= 75% BCF 10^9 M3 sm 3 /rm 3 Mt CO2 Arcadia 158 4,5 400 5,9 Banquereau 170 4,8 280 9,0 Chebucto 66 1,9 275 3,6 Citnalta 172 4,9 290 8,8 Glenelg 508 14,4 270 28,0 Intrepid 54 1,5 260 3,1 Olympia 143 4,1 350 6,1 Onondaga 304 8,6 250 18,1 Primrose 127 3,6 160 11,8 South Sable 8 0,2 265 0,4 Uniacke 20 0,6 405 0,7 West Olympia 30 0,8 330 1,4 West Sable 93 2,6 170 8,1 West Venture C-62 31 0,9 375 1,2 West Venture N-91 68 1,9 385 2,6 Total 1952,0 55,3 108,8 Table 3 Undiscounted economic model. KUST base case with UFBA cost sensitivities and carbon price sensitivities. Cost comparison to benchmarks.

• Firdush Zallah Hussain • Rhythm Shah • Sonal Janagal • Sushmita Rangnath Mastud Second Place – Federal University of Bahia (Brazil)

• Martín Eduardo Coffey

The teams would like to thank Dalhousie University and the EAGE Green Fund for sponsoring the competition; DivestCo and ION for providing well log and seismic data; Schlum berger for use of Petrel and Eclipse software; and Philip Ringrose for instigating this competition (2019) and providing Theadvice.‘Minus

2012) increase incrementally with depth up to fracture closure pressures (Wielens 2003). This is the result of a dynamic pressure system with pressure entry via disequilibrium compaction and hydrocarbon generation and ongoing pressure release via limited cross-fault juxtapositions between pressure compartments (Rich ards et al., 2008; Skinner, 2016). In principle, overpressure infers containment, but the complications associated with drilling into overpressure (particularly with varying levels of pressure deple tion in fields such as Thebaud and Venture) probably favours hydro-pressured aquifers and fields – not to mention additional drill-depth, and well integrity issues in depleted, originally overpressured, fields.

• Kyle Watts

FEATURE: MINUS CO2 CHALLENGE 88 FIRST BREAK I VOLUME 40 I APRIL 2022

• Arpita Chakraborty

• Ahmed Samir Muhammad Rizk

• Amaar Imdad Siyal

• John Paul Masapanta Pozo

Bentham, M., Mallows, T., Lowndes, J. and Green, A. [2014]. CO2S TORage evaluation database (CO2Stored). The UK’s online storage atlas. Energy Procedia, 63, 5103–5113. Bradshaw, J. and Dance, T. [2005]. Mapping geological storage pro spectively of CO2 for the world’s sedimentary basins and regional source to sink matching. In Greenhouse Gas Control Technologies, 7, 583-591. da Costa, P.V.M., da Costa, A.M. and Meneghini, J.R. et al., [2020]. ASME 2020 39th International Conference on Ocean, Offshore and Arctic Engineering. World’s First Carbon Sequestration Project in Salt Caverns Built Offshore in Ultra Deep Water in https://asmedigitalcollection.asme.org/OMAE/proceedings-abstract/Brazil.OMAE2020/84317/V001T01A029/1092553.

CO2 Challenge 2021’ top 4 teams: First Place – Indian Institute of Technology Bombay (India)

• Mariana Rosário Conceição Sampaio

A fundamental issue is whether to favour deep saline aquifers with their enormous storage potential or depleted/stranded fields that have conventional oil and gas traps. If a test site for deep saline aquifers were to be considered, the Upper and Middle Missisauga Formations in the vicinity of the Kegeshook well (Figures 5 and 7) would meet the criteria of aquifer quality, depth, and well-developed topseals (Naskapi Shale and ‘O’ Marker). Among the depleted and stranded fields, Alma and Glenelg received particular attention from the teams. Alma at around ~2800m subsea is the largest, shallowest, and simplest of the depleted gas fields. Of the stranded fields, Glenelg is one of the shallowest (~3200m subsea). Both have hydro-pressured Upper Missisauga aquifers, below thick Naskapi Shale at the shelf-margin of the delta – which puts them ~200km offshore. Glenelg does have some compartmentalization with multiple contacts in three major fault blocks that result from ‘MercedesBenz’ faulting above a footwall salt diapir (similar to Onondaga and Thebaud). This might stimulate speculation that monetization of a stranded field (P50 508 BCF) could be combined with carbon storage in a depleted field and possible hydrogen/carbon storage in a salt diapir. Along these lines, the shallow (~1400m subsea) West Sable Field (P50 resource 93 BCF gas, 18 MBO oil and condensate), which was discovered by the first well drilled in the basin in 1967, sits above a salt diapir penetrated by a subsequent well at ~3000m subsea.

• Omar Abdulrahman Al Attas Fourth Place – University of Stavanger (Norway)

Acknowledgments

Conclusion This competition presented student teams on five continents with a blizzard of data and published information and some ambitious technical goals that have never been addressed previously on the Scotian Margin — a ‘real world’ project with added complexity during in the Covid epidemic, when team interaction is at a premium in a multi-disciplinary project. The results are very encouraging presenting local, regional, and intercontinental scale opportunities.Eachteam attacked the project in their own way, and they are to be congratulated: providing confidence where solutions converged and, possibly more importantly, stimulating new ideas and discussion where they did not. It reinforces the notion that as we progress the energy transition there is a spectacular base-level of offshore geoscience and engineering knowledge that can be applied to any enterprise involving fluid flow in porous media: oil and gas production, carbon storage, hydrogen or methane storage, aquifer management, open-loop geothermal energy, and technologies that have not even been thought of yet.

• Marcos Reinan de Assis Conceição

• Marwa Mohammed Alblooshi

• Ahmed Khaled Alzaabi

• Matheus Radamés Silva Barbosa

• Alexsandro Guerra Cerqueira Third Place – Khalifa University (United Arab Emirates)

• Orlando Butar Butar CCUS general publications Bachu, S. [2003]. Screening and ranking of sedimentary basins for sequestration of CO2 in geological media in response to climate change. Environmental Geology, 44, 277-289. Bachu, S. [2015]. Review of CO2 Storage Efficiency in Deep saline Aquifers. Int. J. Greenhouse Gas Control, 40, 188-202.

• Aigul Akberova

References – cost and revenues Gorman, M. [2022]. N.S. government prepares carbon pricing plan for next 8 years. Leung,JaremkoHenderson.change-greenhouse-gas-emissions-carbon-prices-1.6336937.https://www.cbc.ca/news/canada/nova-scotia/climate-J.[2021].HalifaxExaminer.AltonGasprojecthalted,sitetobedecommissioned.[2021].DepletedSableOffshoreEnergyProjectRemediationLikelyCompleteBy2021https://www.naturalgasintel.com/depleted-sable-offshore-energy-project-remediation-likely-complete-by-2021/.D.Y.,Caramanna,G.andMaroto-Valer,M.M.[2014].Anoverviewofcurrentstatusofcarbondioxidecaptureandstoragetechnologies

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OERA,OERA,OERA,https://oera.ca/research/sydney-basin-play-fairway-analysis-atlas-2017.https://oera.ca/research/play-fairway-analysis-atlas.https://oera.ca2011.Atlas.PlayFairwayAnalysisOffshoreNovaScotiaCanada.2017.SydneyBasinPlayFairwayAnalysis.2019.ShelburneBasinPostmortemAnalysis.

States and Canada. Vidas, H. et al. [2012]. Analysis of the Costs and Benefits of CO2 Sequestration on the U.S. Outer Continental Shelf. Prepared Under BOEM Contract M10PC00117 by ICF International. Canada Nova Scotia Offshore Petroleum Board (CNSOPB) SableKidston,Kendell,EnCanaBrentonBrown,https://www.cnsopb.ns.ca/resource-type/monthly-production-reportshttps://www.cnsopb.ns.ca/what-we-do/information-management/https://www.cnsopb.ns.cadata-management-centreD.E.[2008].RegionalGeologyoftheScotianBasin.Canada-NovaScotiaOffshorePetroleumBoard.M.andSmith,etal.[2014].ResourceAssessmentofUndevelopedSignificantDiscoveriesontheScotianShelfNovaScotia,Canada:Canada-NovaScotiaOffshorePetroleumBoard.[2006].DeepPanukeOffshoreGasDevelopmentPlan.K.andDeptuck,M.[2012].LowerCretaceousshelf-edgetrajectories,shelf-indentingcanyons,andthepotentialtransferofcoarserclasticsintodeeperwater,SableSubbasin,offshoreNovaScotia.GeoscienceOpenFilePoster2012-002PF.Canada-NovaScotiaOffshorePetroleumBoard,2panels.A.G.,Brown,D.,Smith,B.M.andAltheim,B.[2007].TheUpperJurassicAbenakiFormationOffshoreNovaScotia:ASeismicandGeologicPerspective.Canada-NovaScotiaOffshorePetroleumBoard,Halifax,165p.OffshoreEnergyLtd.[1995].SableOffshoreEnergyProjectDevelopmentPlanApplication,Volumes1-5. Geological

Resource classifications Society of Petroleum Engineers, 2017. CO2 Storage Resources Manage ment System. United Nations [2019]. United Nations Framework Classification for Resources. ECE ENERGY SERIES No. 61. Basin and Reservoir Lab. Dalhousie University

Natural

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Dusseault,O’Connor,Pothier,https://www.dal.ca/faculty/science/earth-environmental-sciences/research/basin-reservoir-lab/publications-.htmlH.D.,Wach,G.D.andZentilli,M.[2010].ReservoirandSealPairs:CarbonSequestrationinAtlanticCanada,GeoCanada2010,ProgramwithAbstracts,May10-14,2010,Calgary,Canada.D.,Richards,B.,Angel,M.andWach,G.[2019].DynamicModelingofBuoyantFluidFlowinRolloverAnticlines,OffshoreNovaScotia,Canada:ImplicationsforHydrocarbonDistribution,PotentialCarbonCaptureandStorage(CCS)andFutureActivityintheSableSubbasin.Energy3Canada’sEnergyConference,Halifax,NovaScotia.October16-18,2019.M.B.andWach,G.D.[2020].GreeningtheMaritimegrid—let’sleadworldinenergytransition.https://www.saltwire.com/nova-scotia/opinion/maurice-b-dusseault-grant-wach-greening-the-maritime-grid-lets-lead-world-in-energy-transition-489931/.

Wade,https://basin.gdr.nrcan.gc.ca/index_e.phphttps://www.nrcan.gc.caJ.A.andMcLeanB.C.[1990].The in Keen, M.J. and Williams, G.L. (Eds.), Geology

. Renewable and Sustainable Energy Reviews, 39, 426McCollum,443. D.L. and Ogden, J.M. [2006]. Techno-economic models for carbon dioxide compression, transport, and storage & correlations for estimating carbon dioxide density and viscosity. MIT [2016]. Boundary Dam Fact Sheet: Carbon Dioxide Capture and Storage Project http://sequestration.mit.edu/tools/projects/ index_cancelled.html Dusseault, M.B., Bachu, S. and Rothenberg, L. [2004]. Sequestration of CO2 in Salt Caverns. Journal of Canadian Petroleum Geology Vol. 43(11), p49-55. Gammer, D., Green, A., Holloway, S. and Smith, G. [2011]. The Energy Technologies Institute’s UK CO2 storage appraisal project (UKSAP). SPE Offshore Europe Oil and Gas Conference and Exhibition, Society of Petroleum Engineers, Aberdeen, UK. IEAGHG [2009]. CO2 Storage in Depleted Gas Fields (Issue 2009/01). IPCC [2005]. IPCC Special Report on Carbon Dioxide Capture and Storage. Prepared by Working Group III of the Intergovernmental Panel on Climate Change [Metz, B., O. Davidson, H. C. de Coninck, M. Loos, and L. A. Meyer (eds.)]. Cambridge University Press, Cambridge, United Kingdom and New York, NY, USA, 442 NPDpp.[2019]. Norwegian Petroleum Directorate. CO2 storage Atlas Norwegian North Sea. Ringrose, P.S. and Meckel, T.A. [2019]. Maturing global CO2 storage resources on offshore continental margins to achieve 2DS emissions reductions. Scientific reports, 9(1), pp.1-10. Ringrose, P. [2020]. How to Store CO2 Underground: Insights from Early-Mover CCS Projects; Springer: Berlin/Heidelberg, Germany. U.S. Department of Energy [2010 & 2015]. Carbon Sequestration Atlas of the United Survey of / Resources

geology of the southeastern margin of Canada:

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