Issuu

OCTOBER 2019

THE MAGAZINE OF THE PETROLEUM EXPLORATION SOCIETY OF GREAT BRITAIN

I LOVE MY FAULTS!

GeoJim always worried that he could never model faults and contorted cells adequately and then run dynamic simulations. Find out how tNav Tim introduced him to a simple, elegant and integrated solution.

Follow Timâ€™s adventures at www.tNavigator.com/Tim #tNavTim

GEOLOGY

SIMULATION

UNCERTAINTY

NETWORK MODELLING

A word from the President

PES

A WORD FROM THE PRESIDENT

Exciting PROSPEX ahead in 2019 … The summer is now in the past and the holidays - which I hope you enjoyed - seem for me a distant, but happy memory. In our industry, the autumn typically is characterised by companies examining and updating their corporate strategies for the year ahead. Technical and Operating Committee meetings will take place between licence operators and their joint venture partners to consider and agree work programmes and their associated budgets for 2020 and beyond. The price of oil continues to provide a challenge to the industry’s appetite for investment into new and existing projects. The start of 2019 saw oil prices increase by around 40% from $54 per barrel to $75 per barrel in April. Since then, despite fluctuations through the summer months, the price of oil has softened to around $60 per barrel by early September, which is still some 14% above prices achieved at the start of 2019. Forecasts made by some analysts suggest that Brent crude will be

trading at around an average of $65 in 2020. As an industry we have to continue to balance E&P investment decisions against an unpredictable and volatile commodity price – but it was always thus! However, business continues as usual as is evidenced by the ongoing UKCS 32nd Offshore Licensing Round which opened back in July and closes next month. As the TCM and OCM season comes to a close, the PESGB, through its PROSPEX Conference, provides the industry with the opportunity for companies to promote and market investment business opportunities to their peers. As on previous occasions, this year PROSPEX will take place at the Business Design Centre in Islington between 11th and 12th December. For those members who have not yet had the opportunity to attend, PROSPEX makes use of an exhibition area where booths exist for companies to promote and display the geotechnical details of

As an industry we have to continue to balance E&P investment decisions against an unpredictable and volatile commodity price – but it was always thus!

their respective projects to delegates. In addition, there is a rich and varied programme which includes key note and technical presentations on a range of topics which takes place over the two days through a series of regional sessions. PROSPEX 2018 was a great success with some 72 exhibiting companies attracting the attendance of more than 800 delegates. As with all its events, the PESGB aims to provide value for money to its members and sponsors. Registration is now open and members can attend the two day event at a cost of £186 each, which includes lunch and refreshments. Similarly, competitively priced booths are available to exhibitors. In previous years, PROSPEX has attracted attendance not just from the North Sea arena but also from international delegates. If you are interested in attending, PROSPEX offers great networking opportunities to those companies that wish to attract new investment partners as well as to those companies looking for new business development opportunities. Lastly, I would like to thank those candidates who are standing in the current PESGB Council elections. By now, you will have received email notification that voting is open and closes on the 11 November, so I urge you to cast your vote promptly. The results of the election will be published in the December edition of the PESGB Magazine. I look forward to seeing some of you at PROSPEX, if not before at the October and November PESGB evening lectures, details of which can be found in this issue of the Magazine.

Martin Durham PESGB President 2019 president@pesgb.org.uk PESGB October 2019 3

PES

OCTOBER 2019

Inside this issue…

EVENTS

N E W S F E AT U R E S

International Asia Pacific North Sea PA G E S 5 2 - 5 9

PA G E 2 2

COMMUNITY

Members on the Move

An overview of the largest shale gas field in China PA G E 4 8

PA G E 3 9

Young Professionals

North America to drive global LNG

PA G E 4 0 - 4 1

2020 PESGB Council supply growth Elections PA G E 6 0

PA G E 4 3

Events p8-36 • Community p39-45 • News p48-63 • Directory p64-66 On the cover: The Aldeyarjarfoss Waterfall pours over columnar basalt of the Frambruni lava field close to the Sprengisandur Highland Road in northern Iceland (Photo: Jon Noad) 4 PESGB October 2019

Oil Finders Lunch The Greater Buchan Area development OCTOBER 1-2 Africa E&P Conference Olympia London 3 Machine Learning SIG Meeting PESGB Offices, Victoria 8 London Evening Lecture The Geological Society of London 15 Aberdeen Evening Lecture Jurys Inn Aberdeen 17 DrillingInfo event PESGB Offices 22 Onshore SIG Meeting Fox and the Green NOVEMBER 5 London Evening Lecture The Geological Society of London One week earlier than usual 7 Machine Learning SIG Meeting PESGB Offices, Victoria 19 Technical Excellence Workshop PESGB Training Room

19 Aberdeen Evening Lecture Jurys Inn Aberdeen

With David Larcombe, Jersey Oil & Gas

19 Old Timers PESGB Training Room 20 Surrey Branch Meeting The White House, Guildford 22 ICL Boulby Mine Field Trip 28 Oil Finders Lunch The Atholl Hotel

The Beechgrove Suite, Atholl Hotel, Aberdeen Thursday 28 November 2019 A buffet lunch will be served at 12 noon. Presentation starts at 12:15, followed by the farmout slot and UK E&A Drilling Update. Event concludes by 13:30. Register for only £8 at www.pesgb.org.uk/events/oil-finders-lunch-7/

DECEMBER 3 Granite City Reception Underdog 5 Machine Learning SIG Meeting PESGB Offices, Victoria 11-12 PROSPEX Business Design Centre 12 President’s Evening Grays Inn

Jersey Oil & Gas has recently been awarded acreage in the 31st Supplementary Offshore Licensing Round including the Buchan oil field, the J2 and Glenn oil discoveries. David Larcombe, Engineering & Commercial Manager will outline JOG’s thoughts in relation to the development of the Greater Buchan Area and some of the challenges and opportunities it presents.

PESGB October 2019 5

ABOUT YOUR MAGAZINE

PES Est. 1964

To promote, for the public benefit, education in the scientific and technical aspects of petroleum exploration

EXECUTIVE COUNCIL President Martin Durham, Egdon Resources President Elect Beverley Smith Vice President David Offer, RPS Energy Treasurer Gavin Ward, RISC Advisory Secretary Raquel Arzola, Edison E&P UK Ltd Director Aberdeen Nick Allan, The Parkmead Group

Please note that this magazine is produced solely for members’ convenience. Circulation is restricted to members of the Society, who are issued with one copy. Additional copies are not available for sale. Although the PESGB does not intend to publish or circulate any article, advertisement or leaflet containing inaccurate or misleading information, the Society cannot accept responsibility for information contained in the magazine or any accompanying leaflets that are published and distributed in good faith by the PESGB. Items contained in this magazine are contributed by individuals and organisations and do not necessarily express the opinions of the PESGB, unless explicitly indicated. Any enquiries regarding advertisements should be made to the advertisers themselves and not to the Society. The PESGB does not accept responsibility for items, articles or any information contained in or distributed with the magazine. Reproduction of the magazine in any form is strictly prohibited. Usage of the magazine or any of its contents for commercial purposes is strictly forbidden. © PESGB 2019

H AV E Y O U R S AY The PESGB welcomes contributions, comments, articles and feedback from the Membership. If you would like to comment on anything you read in the magazine, or perhaps you have an item you would like to be considered for inclusion, please email editor@pesgb.org.uk For advertising enquiries please contact Production Editor Jay Patel at jay@pesgb.org.uk Deadlines for future issues of the PESGB magazine are: November: 1 October

December: 1 November

TA K E N A N Y G R E AT P H O T O S ?

Director Elect Aberdeen James Churchill, Shell Director Young Professionals Nick Holgate, Shell International Director Education & Training Andy Racey Director Outreach Amanda Turner, Lir Resources Director Communications Tracey Dancy, Making Waves Marketing Past President Neil Frewin, Shell International Past Aberdeen Director Henk Kombrink, Lloyd’s Register

PESGB, 3rd Floor, Welby House, 96 Wilton Road, London, SW1V 1DW 020 7408 2000 pesgb@pesgb.org.uk Registered charity no. 1085619

We are always looking for photographs for future covers of the PESGB magazine. If you have some interesting pictures, especially landscape or geological subjects and you are happy to allow their unrestricted use by the PESGB, we would be pleased to hear from you. Please send any images by email to jay@pesgb.org.uk and remember to provide a suitable caption for your images and some context if possible. MEET THE PESGB TEAM Maria Iredale, Executive Director | Samuel Akinwonmi, Finance | Rosy Chirayath, Marketing | Rebecca Dibley, Events | Sunaina Krishna, Events | Jay Patel, Magazine |

pesgb.org.uk 6 PESGB October 2019

Simona Pzson, Events | Laiqah Shah, Membership | Jennie Teehan, Events

W E L B Y H O U S E , 9 6 W I LT O N R O A D , L O N D O N , S W 1 V 1 D W

The PESGB offers a bright, modern, central London venue for meetings, workshops and events. Located in a pleasant street by Victoria Station, our office offers a choice of 2 fully-accessible conferencing and meeting rooms, bookable five days a week.

F U L L D AY (9.00-17.00) Sustaining Sponsor £800+VAT Member £880+VAT Non Member £1,000+VAT

TRAINING ROOM C A PA C I T Y 4 0

H A L F D AY (9.00-12.30/12.30-17.00) Sustaining Sponsor £490+VAT Member £540+VAT Non Member £600

Need a venue? Get in touch...

Excellent location Easy to book Helpful friendly staff Convenient space Will definitely repeat-book this venue

BOARDROOM C A PA C I T Y 1 4 F U L L D AY (9.00-17.00) Member £380+VAT Non Member £500+VAT H A L F D AY (9.00-12.30/12.30-17.00) Member £240+VAT Non Member £300+VAT

For further information please visit pesgb.org.uk/commercial/venue-hire/ or contact pesgb@pesgb.org.uk or on 0207 408 2000PESGB October 2019

PES LONDON EVENING LECTURE ABSTRACT THE GEOLOGICAL SOCIETY OF LONDON, BURLINGTON HOUSE, PICCADILLY, W1J 0BD 8 OCTOBER 2019, 6PM

An overview of the largest oil discovery on the Northwest Shelf of Australia in the last 30 years With Ian Cockerill, RISC Advisory The Dorado field was discovered by Quadrant Energy (now Santos) and partners Carnarvon Petroleum in August 2018. Carnarvon Petroleum released a 2C Gross Contingent Resource of 186 million barrels of oil and condensate and 552 Bscf of Gas (20 August 2018) making Dorado the largest oil discovery made on the Northwest Shelf in the last 30 years and far exceeding the pre-drill (gross, Pmean) estimate of 125 million barrels of oil equivalent. Dorado is located in the Bedout sub-basin 160km north of Port Hedland in approximately 90m of water. The reservoirs are at a depth of around 4000m in the Caley, Baxter, Crespin and Milne clastic units of the Lower Triassic Keraudren Formation. The Bedout sub-basin covers an area of approximately 15,000km2.

Six wells were drilled in the basin between 1971 and 1983 including what was originally interpreted to be a tight gas discovery in the Phoenix-1 and Phoenix-2 wells. Despite the early indications of a proven petroleum system, exploration drilling in the area didnâ€™t return until 2014 with the Phoenix South discovery. The Roc discovery followed in 2016 and Dorado (2018) has rounded up a record of 100% geological success for exploration drilling in this renewed period of activity in the Bedout. The Dorado prospect was a new stratigraphic play concept for the sub-basin, targeting high amplitude seismic events of the Lower Keraudren Formation terminating against a deep incising canyon. The shale-filled Dorado canyon provides the side seal to Dorado. Multiple

prospects have been identified on trend from Dorado on the east-west trending canyon system. The Dorado canyon, and other canyons yet to be tested, have the potential to extend on to neighbouring open acreage some of which were made available in the Australian 2018 Acreage Release. The 22,000km2 Capreolus 3D Survey owned by TGS covers Dorado, all of the discoveries made in the Bedout sub-basin and the majority of the most prospective part of the Bedout sub-basin. RISC has interpreted this survey and this presentation will describe the Dorado play and highlight other untested plays within this exciting emergent province of the Northwest Shelf of Australia.

Figure 1. Dorado-1 north-south section (Source: Santos ASX Release 22 August 2018) 8 PESGB October 2019

EVENTS

ABERDEEN EVENING LECTURE ABSTRACT JURYS INN ABERDEEN, UNION SQUARE, GUILD STREET, AB11 5RG 15 OCTOBER 2019, Food & drink served from 6:00pm, lecture starts at 6:30pm

“Whatever happened to CSS in the UK?” With Steve Furnival, Principal Reservoir Engineer, Axis Well Technology

Carbon Capture and Storage (CCS) has been talked about in the UK for years; or should that be (for at least a couple of) decades? Worldwide, CO2 has been injected into reservoirs since the early 1970s for Enhanced Oil Recovery (EOR). Whilst not often sourced by Carbon Capture, CO2 EOR can be thought of as a form of Storage as, if successful, the majority of the injected CO2 will remain locked in the subsurface if managed correctly, hence it’s been an important contribution to the technology. The first project in which CO2 was injected into the subsurface purely to avoid emissions to atmosphere was the Sleipner project in Norway. Here, the produced wet gas contains too much CO2 to be injected into the gas grid, therefore the bulk of the CO2 is removed using a chemical plant. But, rather than vent the CO2, Statoil capture, compress and inject the excess CO2 because it’s cheaper than paying the emissions tax introduced by the Norwegian government in 1991. This process has injected around 1.0 million tonnes per year

(Mt/yr) or 52 MMscf/d since start-up in 1996. Statoil, now Equinor, has also operated or been an important partner in other CCS projects in Norway (Snohvit) and Algeria (In Salah). Closer to home, we’ve done a lot of talking. We’ve done a lot of academic study. We’ve even had three projects enter Front End Engineering and Design (FEED) but we’ve never seen a project reach Final Investment Decision (FID). Why not? It’s probably no surprise but a common component in these failures is the UK Government. Back in 2007, it was BP and SSE who were “promised” and then “denied” funding for their DF-1 project which would have seen CO2 from the Peterhead power station injected into Miller. Next was the government’s first CCS competition in 2010 in which E.On was planning to develop a new power plant called Kingsnorth in the Thames Estuary with the resulting CO2 piped to the (very) depleted SNS gas field Hewett with its numerous plugged & abandoned wells; here we note E.On got cold feet about the same time the

government withdrew funding. The second CCS competition saw £1B of “guaranteed” innovation funding withdrawn in Nov 2015 from the Shell & SSE Peterhead/Goldeneye and the Drax, Alstom, BOC & National Grid White Rose projects. Yes, big sums of government money, i.e. our tax, but small compared with the cash that has been invested in renewables, plus what will be required to get the Hinkley Point-C nuclear plant built and operating. So, given this history, why would any company or consortia even bother trying to develop CCS in the UK? Well, young Greta Thunberg and the greater environmental movement might be focusing minds, but even before she became headline news there were several projects already in development. We’ll discuss three such projects, Northern Lights (in Norway), Acorn and the Clean Gas Project (in UK). These projects are not necessarily focussed on abated power production but the decarbonisation of heavy industry, something renewables will find challenging. PESGB October 2019 9

1 - 2 O C T O B E R 2 0 1 9 | O LY M P I A L O N D O N

R E G I S T E R N O W AT

https://africa.pesgb.org.uk/ PESGB/HGS Member | £500 Non-member | £576

AFRICA IS BACK SMARTER STRONGER BETTER This annual event, alternating between London and Houston, has established itself as the primary technical E&P conference and exhibition on Africa. The Africa E&P Conference 2017 was attended by over 600 delegates, with more than 30 countries represented including Congo, Comoros, Gabon, Guinea, Madagascar, Mozambique, Namibia, Nigeria, Sierra Leone and South Africa. Reflecting the high-quality technical content, 50% of the audience is G&G, with 20% of the audience identifying themselves as C-level executives.

#AfricaEP2019 @PESGB

GET IN TOUCH For more information, please get in touch with mandg@pesgb.org.uk or call 01224 646311 10 PESGB October 2019

60% of attendees were Presidents / VP / Directors / Exploration Managers / Senior Explorationists / Chief / Senior Geophysicists and Geoscientists

Over 250 companies represented at Africa 2017

This year the PESGB has received over 90 high quality abstract submissions which will form a diverse and relevant technical programme. Submissions have once again come from across the industry spectrum and include oil companies, service companies and academia. All the main prospective regions of Africa will be considered. We are looking forward to papers on, recent discoveries and forthcoming wells in Africa, including high impact and play-opening wells presented by their Operators. Technical overviews of basins hosting licences rounds will provide a unique opportunity to fast track your technical knowledge ahead of bid deadlines. A range of submissions provide an overview of technical workflows that set the standard for industry best practice. Once again the conference will be the “go to” for Africa E&P activity and in-depth geological understanding of the continent.

29%

of the audience was international with representation from: Comoros, Mozambique, Sierra Leone, South Africa, Namibia, Guinea, Congo, Madagascar, Gabon, Nigeria, São Tomé & Príncipe

PRE-CONFERENCE WORKSHOP AFRICA’S THERMAL REGIME A N D I T S I M PA C T O N PETROLEUM SYSTEMS Monday 30 September | Hilton London Olympia COURSE SPONSOR

There has been increased attention in recent years to Africa’s past and present thermal regime, as recent discoveries (particularly those of gas and continuing into 2019) have frequently demonstrated the influence of high heat flow events. This workshop has the objective of improving our knowledge of Africa’s thermal history to enable improved predictability of source rock maturity and hydrocarbon phase, particularly by enabling analogue constrained input to basin modelling. There will be four sessions with two speakers each, looking at the themes of the Present Day thermal regime (including presentation of a database with over 2000 points), analysing the Past, hydrothermal events and specifics of deep water West Africa. Each of these will include a discussion session where the limited audience of 40 will be encouraged to share their own experiences.

AGENDA 9.00 - 10.30 What we know/the Present Day. Source rocks of Africa. Present Day thermal regime of Africa and its controls. Duncan Macgregor (MacGeology) & Christine Yallup (Halliburton) 1 0 . 3 0 - 1 0 . 4 5 | B R E A K 10.45 - 12.30 Modelling the Past. Approaches and Pitfalls. High heat flow events on extended and transform margins Helen Doran (Ola Geoscience) & Tiago Cunha (Integrated Geochemical Interpretation) 1 2 . 3 0 - 1 3 . 3 0 | L U N C H 13.30 - 15.00 Hydrothermal and Extreme Events. Hot fluids in Kwanza/Senegal Basins. Multiple hot events in Algeria/NW Africa. Nick Cameron (GeoInsight Ltd) & Duncan Macgregor (MacGeology) 1 5 . 0 0 - 1 5 . 1 5 | B R E A K 15.15 - 16.30 Contrasting Thermal Histories in Angola and Gabon Roger Baudino (Repsol) & Helen Doran (Ola Geoscience)

Register at www.pesgb.org.uk/africa-2019 PESGB Members | £290.00 + VAT Non-members | £330.00 + VAT Please note you can also purchase the workshop as an add-on to your Africa E&P Conference 2019 Ticket

SOCIAL EVENTS SPEED NETWORKING

AFRICA CONNECT Monday 30 September, 17.30 – 18.30 Kensington Suite, Hilton London Olympia

NEW FOR 2019

Start networking early and join us for our inaugural Africa Connect event, taking place ahead the Africa E&P Conference Icebreaker

Looking for a way to meet people outside of your network and establish new relationships with like-minded professionals? Speed networking is quick, efficient and fun! Particularly designed to facilitate networking between participants with fewer years’ experience and seasoned conference attendees, this is a great opportunity to make new contacts through one-on-one focused conversations, each lasting just a few minutes. Taking place immediately prior to the Icebreaker Reception and open exclusively to participants of the Africa E&P Conference 2019, this is a great opportunity to begin networking early! Register to attend this free event at www.pesgb.org.uk/africa-2019

ICE BREAKER

Monday 30 September, 18.30 - 20.30 Westminster Suite, Hilton London Olympia

NETWORKING RECEPTION

Tuesday 1 October, 17.30 - 19.30 Exhibition Floor, Conference Centre, Olympia London PESGB October 2019 11

MAIN AUDITORIUM 08.30

R E G I S T R AT I O N & C O F F E E SESSION 1: OVERVIEW & INSIGHT FOR AFRICA Session Chairs: Helen Doran & Kevin Dale

O R A L P R O G R A M M E | T U E S D AY 1 O C T O B E R

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Welcome & Introduction Dr Özlem Adiyaman Lopes, Natural Sciences Sector, UNESCO Reserve growth: the impact on exploration performances assessment, and the Africa case Lorenzo Meciani, Eni SpA MSGBC : an integrated approach to accelerate exploration V.Curinier, TOTAL Bringing North Sea Technology to the Ultra Deep Waters Offshore Ghana Ståle Monstad, Aker Energy Controls on Lateral Seal Development in DW Stratigraphic Traps of the Atlantic Basin Colin Grant, Shell International E&P COFFEE & POSTERS S E S S I O N 2 : H Y D R O C A R B O N H A B I TAT O F D E E P W AT E R A F R I C A Session Chairs: Duncan Macgregor & Richard Blight

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East Africa Gas: Source type or maturity? Michael Sullivan, ExxonMobil International Limited Oil along the East African margin: a regional 3D integrated charge modelling approach Jimmy Van Itterbeeck, Shell International E&P Application of “Ranking Biogenic Gas _RGB” tool for evaluating Eastern Mediterranean Biogenic Potential Sara Camici, Eni SpA 4D Temperature Modelling of Potential Biogenic Gas Fairways in the Eastern Mediterranean Thomas Butt, Halliburton LUNCH & POSTERS SESSION 3: ONSHORE AFRICA: UNLOCKING THE POTENTIAL Session Chairs: Jerry Jarvis & Harry Davis

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12 PESGB October 2019

Structure and Tectonic Evolution of the Intracratonic Congo Basin – an update Damien Delvaux, Royal Museum for Central Africa Delivering 100% exploration drilling success in Niger: Geological fundamentals and future potential Bill Wilks, Savannah/Merlin Energy Resources Ltd COFFEE & POSTERS Rejuvenating Exploration in the under-explored Southern Termit Basin, Block H, Chad Lorna Blaisse, Delonex Energy Opening new plays in Onshore Côte d’Ivoire. What’s the big idea? Lessons learned from East African Rifts Keryn Simpson, Tullow South Africa Pty Ltd EVENING RECEPTION

CONFERENCE ROOM ONE 08.30

R E G I S T R AT I O N & C O F F E E INTERACTIVE SESSION: SEISMIC WORKSHOP Session Chairs: Ken McDermott & Jason Sutton

O R A L P R O G R A M M E | T U E S D AY 1 O C T O B E R

09.20

OVERFLOW FROM MAIN AUDITORIUM

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Hunting micro-continents offshore East Africa and in the West Indian Ocean Gregor Duval, CGG Deepwater Nigeria: de-risking plays through new maturation and charge scenarios Felicia Winter, AME, TGS Insights into the development of the Ghana Transform Margin and its future play potential from newly acquired long-offset seismic reflection data Neil Hurst, ION LUNCH & POSTERS Interpreting the 4D seismic response using a patchy cement workflow: application to the Jubilee oil field. Ghana Jeremy Neep, Ikon Science Ltd Role of 2D Seismic Data in Giant Discoveries – Brulpadda and other Atlantic Margin Case Studies Karyna Rodriguez, TGS The Republic of Guinea: Shelf Edge Plays meet Syn-Transform Structures Pierre Le Barbanchon, PGS COFFEE & POSTERS THE E&P ACCESS FORUM Session Chairs: Helen Doran & Keith Myers

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What next for E&P in Sub-Saharan Africa? Emma Woodward, Enverus From Resource to Revenue: Turning Discoveries into Commercial Success in an New Industry Landscape Will Scargill, GlobalData Latest Developments on Fiscal Terms and Bidding Criteria for Gabon’s 12th Offshore Licensing Round Noel Mboumba, Gabonese Minister of Hydrocarbons EVENING RECEPTION PESGB October 2019 13

MAIN AUDITORIUM S E S S I O N 4 : F R O N T I E R & E M E R G I N G E X P L O R AT I O N Session Chairs: Fabio Lottaroli & Vincent Delhaye-Prat

O R A L P R O G R A M M E | W E D N E S D AY 2 O C T O B E R

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Frontier and Emerging play exploration in Africa since 2007 Keith Myers, Westwood Energy Group Egypt’s Red Sea: Overlooked Potential in a Young Rift Basin? Sigrún Stanton, Halliburton Magnetic isochrons, provenance history and process sedimentology: using integrated regional geoscience to aid understanding of source and reservoir distribution, offshore South Africa Clare Glover, ExxonMobil COFFEE & POSTERS Long-lived episodic magmatism on the North Gabon margin – does this explain the observed elevated heatflows? Mike Norton, Greenwich Tectonics Limited Reviving the Cretaceous clastic plays in southern Namibia Jochem Bijkerk, Shell International E&P Unlocking the potential of Africa’s Forgotten Transform Margin; the Outeniqua Basin, South Africa Gavin Elliott, New Age (African Global Energy) LUNCH & POSTERS S E S S I O N 5 : T H E C E N T R A L AT L A N T I C M A R G I N S Session Chairs: Louise Hornby & Christian Thomas

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Late Cretaceous/Early-Mid Tertiary crustal deformation and uplift history of the NW African passive margin (Morocco) and implications for deep-water exploration. Richard Bray, Subsurface Resource Consulting The interplay of carbonate platforms and siliciclastic influx during the Jurassic along the Moroccan Atlantic Margin: Controls and impact on reservoir distribution. Aude Duval-Arnould, University of Manchester The Cretaceous deep-water carbonate to siliciclastic transition in the Senegal Basin – insights into provenance, sediment routing and depositional mechanisms from outcrop and core Colm Pierce, CASP COFFEE & POSTERS SESSION 6: UNLOCKING THE POTENTIAL OF AFRICA’S TRANSFORM MARGINS Session Chairs: Matt Warner & Ken McDermott

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16.15 16.30 14 PESGB October 2019

Structure and hydrocarbon prospectivity of the Lower Cretaceous offshore Dahomey Basin, West Africa: A new syn-rift half-graben play opener in the West African Transform Margin Babangida Jibrin, Lekoil Why do turbidite reservoirs offshore Ghana stack to the west, and what impact does this have on reservoir heterogeneity, connected volumes, well placement and exploration? Bryan Cronin, Tullow Ghana Ltd South Africa: South Outeniqua and Mallory Basins, structural complexity of a new petroleum province P Chaffel, TOTAL A W A R D S C E R E M O N Y P R E S E N T E D B Y P R O F. I A I N S T E W A R T C L O S I N G A D D R E S S & I N V I TAT I O N T O H O U S T O N 2 0 2 0

CONFERENCE ROOM ONE THE E&P ACCESS FORUM Session Chairs: Kevin Dale & Caleb Dadson

O R A L P R O G R A M M E | W E D N E S D AY 2 O C T O B E R

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Exploration play types of Madagascar: an overview Hoby Raharisolofo, OMNIS Lower Congo to Namibe â€“ A regional assessment of remaining exploration potential offshore Angola David Barlass, Schlumberger New insights into the geological understanding and prospectivity of the Orange Basin, offshore Namibia Simon Tobias, NAMCOR Understanding the Potentiality of the Libyan Offshore in View of the Zohr Discovery Salah El-Ekhfifi, NOC Libya COFFEE & POSTERS INTERACTIVE SESSION: GEOLOGICAL WORKSHOP Session Chairs: Ben Sayers & Louise Hornby

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The creation of the African margins and the Mesozoic demise of Gondwana Colin Reeves, Earthworks The Structural And Tectonic Evolution Of The West And Equatorial African Margins: A Key To Understanding Hydrocarbon Accumulations Jon Teasdale, Geognostics International Limited Comparative Geothermal Gradients and Heat Flows between African Basins Duncan Macgregor, MacGeology Ltd LUNCH & POSTERS De-risking hydrocarbon charge in the Namibe Basin (southern Angola) using combined 2-D and 3-D petroleum systems modelling techniques Tiago Cunha, Integrated Geochemical Interpretation Ltd Evolution of sandstone composition through the Cretaceous and its impact on reservoir quality along the West African Transform Margin Simon Greenfield, Core Laboratories UK Robust Facies Modelling: Improving Geopressure Assessment Sam Green, Ikon Science Ltd. Where are the Mesozoic paleo-shelf plays in the West Africa Salt Basins of Gabon, Congo and Angola; undeveloped or overlooked? Matt Tyrrell, PGS AMME Defining the tectonostratigraphic framework and new play potential of offshore West Africa (Gabon to Angola) within a regional South Atlantic context using mega-regional seismic data Lisa Fullarton, ION Geophysical AWARDS CEREMONY IN MAIN AUDITORIUM PESGB October 2019 15

SESSION 1: WEST AFRICA

The Effect of Deghosting on the 4D Response: Usan field, Nigeria Philip Smith, ION Reservoir distribution in the Niger Delta. The key for unlocking commercial success Syed Dabeer, PetroVision Energy Services The results of recent fieldwork and oil sampling from onshore Benin; strong evidence for oil resources in this high impact, low cost frontier. Matt Lofgran, Elephant Oil A Review of Thin Bedded Pay including Determination and Produceability within the Elon field, Equatorial Guinea Benjamin Panting, Royal Holloway, University of London Structural Controls on Reservoir Presence along the West African Equatorial Transform Margin: Key Rock-Based Observations Anne McAfee, Core Lab

SESSION 2: NORTH AFRICA

Deepwater Hydrocarbon System, North and South Atlantic Rift Interaction, Equatorial Margins, West Africa and South America Ken Nibbelink, JHI Associates (BVI); Atlantic Basin Consultants LLC Micro-seepage mapping using satellite imagery: Examples from N. Africa Mark Broadley, NPA-CGG Structural history of the Jeffara Â Fault System, NW Libya Giuma Reeh, Target Exploration Analysis of the pre- and post-Variscan unconformity deformations: new insights for the characterization of the Ordovician and Triassic reservoirs in the southern Chotts Basin, Tunisia Pierre-Olivier Bruna, Mazarine-Energy B.V. Unlocking unconventional resources in Libya Cristina TomĂŠ, IHS Markit Contribution of volcanics to hydrocarbon production of fractured reservoirs of Libya: A review Muhammad W Ibrahim, Target Exploration Consultants Ltd Volcanically Driven Fluid Flow and Hydrocarbon Charge in the Pre-Salt of the Namibe Basin, Angola Nathan Rochelle-Bates, University of Manchester SESSION 3: SOUTHERN AFRICA

P O S T E R P R O G R A M M E | T U E S D AY 1 O C T O B E R

Halokinesis and sedimentary patterns in carbonate platforms and siliciclastic deltaic systems: 3D seismic examples offshore Gabon Paolo Esestime, TGS

Sedimentological analysis of pre-salt lacustrine pools in the onshore Namibe Basin, Southern Angola Gustavo do Couto Ramos Pereira, University of Manchester Understanding the petroleum system evolution in the Namibe Basin (Angola): the importance of characterising burial vs local source rock thermal maturation in volcanic margins Edoardo Fiordalisi, University of Manchester An insight into complex charge history and hydrocarbon distribution in Kwanza Basin, Angola Sugandha Tewari, WesternGeco The impact of New Licensing Rounds in Angola and why they may absorb a decade of West African exploration budgets Gayle Miekle, Frontier Using a Source to Sink Study to De-Risk Reservoirs in the Algoa and Gamtoos SubBasins, South Africa Jean Malan, Getech Group plc The present day shelf of the Kwanza Basin; an underexplored link between onshore and deepwater discoveries Matt Tyrrell, PGS AMME Underplating and contourites: controlling the distribution of source and reservoir rocks in the northern Walvis Basin, Namibia Paul Howlett, Royal Holloway University

16 PESGB October 2019

Using 2D seismic for Oil Charge risk reduction in the deepwater plays of NW Africa Neil Hodgson, TGS

SESSION 4: NORTH WEST AFRICA

The enigmatic post-rift and pre-Alpine inversion tectono-sedimentary evolution of the NW rifted continent margin: surprises continue Giovanni Bertotti, Delft University of Technology Dynamic Subsidence, Continental Uplift and Sedimentary Deposition to West Africa’s Passive Margin Bhavik Harish Lodhia, Imperial College London Quantitative seismic geomorphology of The Gambia Mesozoic margin, canyon incision and slope processes Max Casson, University of Manchester Source to sink analysis of Cretaceous sediments along the Central Atlantic passive margin, Senegal Ian Mounteney, University of Manchester; British Geological Survey Senonian unconformity (SNE-like) play in the MSGBC Basin – more to come? Gil Machado, Chronosurveys; Instituto Dom Luiz New Plays in an Exploration Hotspot: AGC Profond, Senegal & Guinea Bissau Michael Bourne, CNOOC International Establishing a high resolution integrated stratigraphic framework for the Berriasian to early Barremian of the Morocco Atlantic Margin Orrin Bryers, University of Manchester Modelling Depositional Systems across Morocco – the limitations of using detrital zircons in understanding source to sink systems James Lovell-Kennedy, University of Manchester Exciting insights from fieldwork in the Ile Sainte Marie Basin, Madagascar Meghan Davies, Robertson, CGG Services (UK) Limited Opening New Plays in East Africa: Predicting the Presence and Nature of Play Elements, offshore Madagascar Matthew Watkinson, EPI Group; University of Plymouth

SESSION 5: EAST AFRICA

P O S T E R P R O G R A M M E | W E D N E S D AY 2 O C T O B E R

New constraints on source to sink systems of NW Africa: provenance analysis of the Mesozoic post-rift clastics in the Essaouira-Agadir Basin (Morocco) Emmanuel Roquette, North Africa Research Group - University of Manchester

Using basin modelling to examine the origin of the hydrocarbons within the deepwater Rovuma Basin of Tanzania, Mozambique and the Comoros Michael C. P. Rego, Rego Exploration Ltd.; Triton Petroleum Pte. Ltd. Offshore Somalia: Frontier Margin Oil Resource Evaluation Karyna Rodriguez, TGS Morondava Basin, Offshore Madagascar: a summary of its hydrocarbon plays and its prospectivity – a promising future awaits Glyn Roberts, Spec Partners Ltd Linking Fieldwork to Regional Seismic: Exploration in an Untested Frontier Province Gillian Barber, BP Influence of contourite activity on Mozambique turbidite systems David Barlass, Schlumberger Exploration potential of a frontier hydrocarbon province - The Angoche basin, Offshore Mozambique Deepak Rathee, WesternGeco A Modern Reworking of the Cabora Bassa Basin, Zimbabwe Casey Edwards, Source Geoscience Pty Ltd Intelligent Geological Target (Basin) Identification (IGTI) – Mpulungu, Zambia Deepti Bisht, Cambridge Geoconsultants Limited Mantle convection and Africa’s Rift architecture: A General Model Neil Hodgson, TGS PESGB October 2019 17

EXHIBITOR BENEFITS

EXHIBIT BEFORE

DURING

AFTER

Listing on the event exhibitor list and floorplan, both online and in upcoming PESGB magazines

Complimentary Passes to the Conference 1 with 4sqm booth 2 with 8sqm booth

Complimentary access to the full Africa E&P Conference 2019 delegate list

1 LinkedIn post and 1 Twitter Post, organised by PESGB Conferences Ltd, stating your involvement in exhibiting at the event

Priority access to booking meeting rooms on-site at the event

Access to the Africa E&P Conference 2019 Post-show Report

Access to the exhibition manual to assist your in preparing for the event

Lunch and refreshments provided throughout the day

Access to event photography

Access to the Exhibitor Marketing Toolkit, helping you to prepare your pre-conference marketing

Company details in the onsite exhibitor guide

Opportunity to book your space onsite for the 2021 show before exhibition space opens to new exhibitors

Access to “We’re Exhibiting” banner ads for additional marketing

Listing on the online event exhibitor list and on the floorplan in literature and signage

Access to the preconference delegate list, prior to the event, to help you with preparations for the event

EXHIBITOR MARKETING TOOLKIT We're committed to helping you make your African E&P Conference 2019 experience as profitable and productive to your business as possible. We will be sending all exhibitors, a copy of the exhibitor marketing toolkit - This pack is intended to act as a helpful checklist and guidelines to support exhibitors in their pre-conference marketing. 18 PESGB October 2019

High-calibre technical content draws the right type of people The only Africafocused show we attended All the best people you want to talk to...

Over 95% of exhibitors surveyed at Africa E&P Conference 2017 said they ‘definitely’ intended to exhibit again

Complementing the outstanding technical conference, the exhibition space will feature industry operators, service companies, national oil companies and professional organisations.

8sqm | £2,500 (+VAT)

Includes shell scheme 2 x spotlights 1 x electrical socket 1 x table 1 x cupboard 2 x chairs

Includes shell scheme 3 x spotlights 1 x electrical socket 1 x table 1 x cupboard 3 x chairs

One complimentary registration

Two complimentary registrations

F E AT U R E A R E A S

SECURE YOUR BOOKING IN 4 EASY STEPS...

4sqm | £1,600 (+VAT)

1. Decide below what size booth you would like 2. Go to the exhibitor floorplan and identify your top four exhibit spaces from the current available positions

INTERNATIONAL PAVILION This designated space provides International representatives with a forum to increase their exposure and promote licensing rounds and/or available acreage to operators, consultants, governments and academia all specifically working or interested in the Africa region. Please contact mandg@pesgb.org.uk for more details

3. Complete the exhibitor application form noting your preferences online at www.pesgb.org.uk/africa-2019

SOLD RESERVED

4. Complete payment as requested by the PESGB office

2019

ENTRANCE

ENTRANCE Poster Session 2 - 10 Posters

5 Posters

Chemostrat Ltd

SDP International Ltd.

2 G1

SEATING

Poster Session 1 14 Posters

ALS Oil & Gas

MERLIN ENERGY RESOURCES LTD 4

Invest in Pau Pyrenees

2 4

DUG 2 2

CATERING 10

3 30

CATERING 11

3 33

ION 4

4 C1 2 Geoex & MCG

Shearwater Geoservices Limited 8

1 Poster

D11

Ikon Science Ltd

OMNIS_

Benin__

RAK Gas LLC 4

Republic of Gabon, Ministry of Petroleum and Hydrocarbons_

2 2

CATERING AND SEATING

2 2

Austinbridgeporth

D9 PetroStrat

2 Posters

International Pavilion

Airbus

PGS Exploration UK Limited

CATERING

Limited

SEATING

Envoi Limited 4

Katalyst Data Management

SRC_

Task Fronterra Geoscience

GeoPartners Ltd

TGS 4 2

G7 G10 PetroVision

Core Laboratories

Poster Session 3 - 16 Posters

G3 Getech

4 CGG Services G6 Moyes & Co.

Energy Services

Canesis

Earthmoves Ltd.

G2 4

Poster Session 4 - 20 Posters

38.5

MEETING ROOM

2 Posters

3.5

MEETING ROOM

1st Subsurface

Consultants Stands x4

H1 RISC Advisory

4.5

THEATRE

4.5

Welcome to the Africa E&P Conference 2019! 1 - 2 October

D3TDI-Brooks

International, Inc.

Westwood Global Energy Group

D7Lynx

Information Systems Ltd

2 2

Limited

4 4 RPS

D14 D15 D16

D12 WesternGeco

Holt Energy Advisors

NVentures Ltd Asset Review Consulting Ltd

North Africa Research Group

Poster Session 5 - 22 Posters

ORGANISERS OFFICE

VISITORS ENTRANCE

CLOAKROOM

PESGB October 2019 19

F1 F2 F3 F4

SPONSOR

WHY SPONSOR? •

• •

Reach a specific and exclusive audience by connecting with over 600 professionals actively interested in the region Increase your visibility before an international audience The Centre for Exhibition Industry Research (CEIR) reports that booth efficiency increases by 104% when sponsorship is included in the exhibition plan.

2019 SPONSORS

Would you like to support the Africa E&P Conference in an alternative way? Flexible and bespoke sponsorship packages are available... Contact events@pesgb.org.uk to discuss the possibilities

HEADLINE R E G I S T R AT I O N | £ 4 , 0 0 0 Make sure your logo is the first thing they see; this popular option includes your logo being printed on the lanyards and badges given to every person attending the conference. TECHNICAL PROGRAMME | £4,000 SOLD Make sure not to be missed & get in front of your audience all day. The Technical program sponsor will have their logo displayed on the main stage throughout the full two days of the conference. A prominent position to make sure your company stands out from the crowd! D E L E G AT E B A G S | £ 4 , 0 0 0 SOLD Make a lasting impression, get your logo on all of the delegate bags. These high-quality satchels or conference folders are not only given to everyone attending as they enter the show but are keepsake items. Ensuring the longevity of your exposure ABSTRACT VOLUME | £4,000 Make sure to be associated with high quality technical content. Your logo will be included on the printed and online abstract volume; a valued technical resource which is an ongoing reference for many people working in the area. EVENING RECEPTION | £4,000 SOLD Networking is one of the top reasons people attend any conference, and the Africa E&P Conference . Make sure that your company is the one to get the party started by sponsoring the Evening Reception; the focal point in the Conference social calendar. Sponsorship will include decorating the event in your branding, and a branded cocktail for attendees on arrival. WiFi | £2,000

MEDIA PA R T N E R

20 PESGB October 2019

This option includes your logo on signage for the WIFI located throughout the seating areas. In addition to having the option to specify password of your choice, meaning everyone attending has to type in your company name each day. SPEAKER GIFTS | £1,000 Get your logo on the gifts which are given out to all of the high profile industry speakers at the Africa conference.

F E AT U R E A R E A S S E I S M I C T H E AT R E | £ 4 , 0 0 0 Back for a second year the second stream of talks at the Africa Conference proved to be a big success! Providing Seismic service companies a better opportunity to ‘show off’ their data. This sponsorship option would allow you to get your logo on the signage in the theatre, a prime spot to be noticed! I N T E R N AT I O N A L PAV I L I O N | £ 2 , 0 0 0 The International Pavilion is a central point to the exhibition floor and as its sponsor your logo would be prominently displayed both in this high profile area and in the specific section of the exhibition website. POSTER AREA | £2,000 Logos on poster areas located on the show floor and on the poster session timetables. SIGNAGE | £2,000 Your logo will be included on all of the directional signage and banners throughout the venue, including both the exhibition floor and conference areas. COURSE | £500 SOLD Sponsor the associated course and get your logo on the course materials and signage.

C AT E R I N G OFFSITE ICE BREAKER DRINKS RECEPTION | £3,000 The first event in the show’s calendar the Ice Breaker Drinks Reception starts the Africa Conference with a bang! To thank you for your sponsorship your logo will be included on signage of the event, including on the drink points. B R E A K FA S T | £ 3 , 0 0 0 Buy everyone a bacon or sausage sandwich, perfect to start the day off right (or mend a sore head), your logo will be featured on the napkins wrapped around each; so people will know who to thank! T E A & C O F F E E | £ 1 , 5 0 0 P E R D AY ...is always a vital part of any conference, and as its sponsor you can get your logo on the coffee cups. Get your brand in their hand. LUNCH | £500 (MAX 2 SPONSORS) SOLD Get your logo on signage on the catering stations over lunchtime. WAT E R C O O L E R S | £ 5 0 0 S O L D They say that humans are 60% water, keep everyone going by sponsoring the water stations, and get your logo on the floorplan at the same time.

GIVE SOMETHING BACK

SPONSORED STUDENT PLACES | £2,000 In order to support the future of our industry we would like to create a programme to support students attending the show. As their sponsor you will be thanked on signage & an article promoting the initiative. YP NETWORKING | £500 For the first time ever we are planning on running a YP ‘speed networking style event. Everyone was just starting out once, this event will facilitate those young or new to the industry in meeting new people to show them the ropes at the conference.

C O N F E R E N C E M AT E R I A L S Sponsoring delegate items make sure that your promotional item goes in the delegate bag given out to each of the attendees. Pens Notepads Delegate list Exhibitor guide Insert

£1,000 - S O L D £1,000 - S O L D £1,000 - S O L D £1,000 £500 PESGB October 2019 21

11-12 DECEMBER 2019 | BUSINESS DESIGN CENTRE, LONDON

R E G I S T E R N O W AT

https://prospex.pesgb.org.uk/ PESGB Member | £186 Non-member | £300

PROSPEX 2018 INCLUDED

25 countries represented

#PROSPEX2019 @PESGB

The Oil & Gas Authority and PESGB are pleased to announce PROSPEX 2019, the UK’s largest prospects fair. We provide a venue for announced Licensees, E&P companies and governments to market their prospects and meet with potential investors to facilitate the deal making process.

delegates 20% international audience

The extensive conference programme offers a contextual overview of licensing activities and related topics for the UKCS, onshore and surrounding areas. As the premier event for promoting prospects in the UK and adjacent areas, PROSPEX creates a “hot spot” by bringing together key industry players and decisionmakers, stakeholders and business leaders. to help advance the value chain from “Prospects to Production.”

22 PESGB October 2019

800+

More than 30 Prospectors promoting 50+ Prospects

Over a quarter of attendees were Directors, C-Level Executives or VPs

WHY EXHIBIT?

• EXIT (down)

STAGE

•

3 9

RPS

Katalyst Data Management

HRH Geology Ltd 9

Co.

3 Moyes &

•

Exploro 9 AS

Danish Energy Agency 9

Seismic Image Processing

28 3

Actis Oil

•

ALS Global

GEPlan

Consulting

OGA

99 s 9

Energy Advisors

25 25Holt

7Zennor

3Petroleum Limited

Catering & Seating Area

NSNR

69 68 Reserved

The Netherlands: EBN and TNO

Egdon PetroTrace Westwood Global Energy9 Resources Ltd Group Plc 9 9

27 3

Bridge Petroleum

Lyme Bay 1st for Consulting Subsurface Western Ardent 9 Ltd 9 Geco 9 Oil 9

Faroese Geological

10 The

GGS

Anderson Anderson &

Brown LLP

Envoi Limited

Corallian

Energy 9

MapStand

Talon Petroleum

18 Syrvey 9

Ireland, Petroleum Affairs

Organisers Office

•

PROSPEX 2019

EXIT

EXHIBIT

Goods Lift

Some of the main benefits include opportunities to:

EXIT 3

EXIT

4 6

Exceed Energy

44 4

PGS

ION

AGR Well Management

Onshore Geophysical Library

PP11

PP12

Cluff Natural Resources

PROSPEX Pavilion

DataCo

Geological Institute

3Polish

PP4 PP5 PP6 PP7 PP8 PP9 PP3 PP10

PP2

PP1

Norwegian Petroleum Directorate

Exploration Geosciences (UK)/Canadian Discovery

Polarcus

Meet decision makers, leading experts in the industry and the media Acquire new customers and speak with existing customers Promote new business and demonstrate your opportunities Attract investment opportunities Promote your licence opportunities through “Prospects to go” and through the exhibition Exhibit side by side with the majors on a level playing field, where small independents and large corporations can attract the same audience

Zenith Europa Oil & Gas Energy Ltd

41 4

TGS

Fraser Well Management

CGG

Rock Flow Dynamics

Catering Area

EXIT

Catering Area

Prices do not include VAT

“A fantastic two days”

PROSPECTOR £1,000 per 9sqm booth before 31 July, £1,200 thereafter We have prospects to promote and our mainstream business activity is prospect generation and/or promotion NON PROSPECTOR £220 per sqm We have no prospects to promote or we promote prospects as an ancillary activity to our mainstream business

OPT IONA L FURNIT URE PA CKA G E: Please indicate below if you would like to add a furniture package to your order which includes table, chairs and a lockable cupboard. £115.00 for 9 sqm £135.00 for 12 sqm £200.00 for 16 / 18 sqm

PAV I L I O N POSTER £400 for one panel If you have booked a Prospector booth, you can indicate your desire to speak about your prospects on the booking form. If you wish to speak on something that would not be regarded as a prospect to go, please contact events@pesgb.org.uk

“Great to meet so many familiar and new faces” “PROSPEX is always an enjoyable and valuable event”

PESGB October 2019 23

SPONSOR

WHY SPONSOR? Promote your company to your target market by connecting with 800+ professionals working in the Petroleum Industry

D E L E G AT E

For those interested in raising their profile to the 800+ expected delegates. Get your name to the forefront of the minds of the key industry players!

Get your brand noticed in the PROSPEX network Advertise your company in the PESGB Magazine, on the PESGB website and through our social media, with a combined reach of more than 6000 people working in the Petroleum Industry and at the show itself to 800+ delegates Align your company with the Oil & Gas Authority and the PESGB

R E G I S T R AT I O N & B A D G E S | £2,500 SOLD Make sure your logo is the first thing they see; this popular option includes your logo being printed on the badges (in black and white) given to every person attending the conference and on the registration desk (in full colour).

B A D G E L A N YA R D S | £ 2 , 0 0 0 S O L D The lanyards will be one of the first items picked up at the conference and are a great way to turn delegates into walking advertising for your company. Your company logo will be printed on all lanyards in full colour next to the PROSPEX logo.

Would you like to support PROSPEX 2019 in an alternative way? Flexible and bespoke sponsorship packages are available... Contact events@pesgb.org.uk to discuss the possibilities All prices are subject to VAT

WiFi | £2,500 SOLD This option includes your company logo on signage for the WIFI located throughout the event. Additionally you have the option to specify login of your choice, meaning everyone attending has to type in your company name each day.

D E L E G AT E L I S T | £ 1 , 0 0 0 Associate your company name with the PROSPEX 2019 delegate list (a full colour PDF) which will be downloadable from the PROSPEX website. With over 800+ industry professionals expected to attend, this is a great way to increase your exposure.

TECHNICAL PROGRAMME | £3,000 SOLD

MEDIA PA R T N E R

24 PESGB October 2019

If you want to associate your company with technical excellence and innovation, this is a great option. The technical programme sponsor will have their logo displayed on the holding slides and signage directing you to the auditorium throughout the full two days of the conference. You logo will also appear on the timetable at the event. A prominent position to make sure your company stands out from the crowd!

E X P L O R AT I O N

You recognise the value of the PROSPEX exhibition to promote exploration and make deals happen. SIGNAGE | FROM £1,500, EXCLUSIVE £3,000 Your logo will be included on all of the directional signage and banners throughout the venue, including both the exhibition floor and conference areas. Place your company logo are multiple points across the show floor. E X P L O R AT I O N M A N A G E R S ’ F O R U M | £2,000 A forum for Exploration Managers, this exclusive event is ideal, if you want to promote your company to a very focused, engaged group. Your company logo will be featured at the event on signage and slides for the Exploration Managers’ Forum hosted at PROSPEX.

NETWORKING

Networking is key in Oil and Gas industries for building professional relationships and facilitating deals. REFRESHMENT BREAKS | £ 2 , 0 0 0 P E R D AY Your logo on the catering stations during your chosen day(s), reaching all the delegates whom are attending the show during one break. INDUSTRY FUTURE

For those who are invested in the future of Oil and Gas. You will be mentioned on all media alongside PESGB and OGA. I N D U S T R Y S H O W PA R T N E R | £ 5 , 0 0 0

NETWORKING RECEPTION | £750 Please contact us for rates for an exclusive sponsor Networking is one of the top reasons people attend PROSPEX 2019. Sponsoring the Networking Reception; the focal point in the Conference social calendar, is one of the best way to put your company at the forefront of people’s minds. Sponsorship will include your company name on the signage at the event. PESGB October 2019 25

TECHNICAL EXCELLENCE WORKSHOPS

Maximising the Use of Core and Core Analysis Data T U E S D A Y 1 9 N O V E M B E R 2 0 1 9 | P E S G B T R A I N I N G F A C I L I T Y, V I C T O R I A

Core is a valuable but under-used resource. Core analysis data can be

With Dr Adam K Moss, AKM Geoconsulting Ltd

used as primary inputs into reservoir

COURSE CONTENT

and petrophysical interpretation models. This course presents strategies for maximising the use of core and ensuring successful data delivery and use. It is designed for those who are planning to

• • •

cut core, and for geoscientists that work

•

with legacy data.

•

W H O S H O U L D AT T E N D Geologists Reservoir Modellers Petrophysicists Reservoir Engineers Technical and Support Staff

Best practice in coring, core handling, processing. Heterogeneity, mineralogy and scale of measurements and their effects on core analysis data. Designing a core analysis test programme for all stakeholders. Understanding laboratory reports and quality checking of core analysis data. An appreciation and understanding of the fundamental core measurements: grain density, porosity, water saturation and permeability.

Teaching includes a combination of short lectures, practical workshops and plenary discussions to consolidate learning. Attendees will have opportunities to share their own experiences, discuss data and explore any issues they may have had relating to core and core analysis data.

6:30pm – 10:30pm

£15 PESGB Members | £20 Guests Includes entrance, 3 drinks and dinner (buffet style)

Granite City Reception 2019 3 DECEMBER 2019 | UnderDog, ABERDEEN

Once again, we are taking this years’ Granite City Reception back to the atmospheric UnderDog, downstairs at BrewDog Castlegate! Join us, old acquaintances and new friends for a wonderfully relaxed evening celebrating a busy 2019 and looking forward to 2020. Register now at www.pesgb.org.uk/events/granite-city-reception-2/ Thank you to our sponsors P L AT I N U M

GOLD

Sponsorship opportunities available, from Bronze at £75 to Platinum at £600 – see the PESGB website for further opportunities and all the details or email rebecca@pesgb.org.uk

PESGB October 2019 27

7pm – 11pm

£46 PESGB Members | £52 Guests Corporate group booking available Tickets include entrance, 3 drinks and food

President’s Evening 2019 12 DECEMBER 2019 | THE HONOURABLE SOCIETY OF GRAY’S INN LONDON

Join us for an evening of celebration in the Inn’s historic Hall, which is the heart of the Inn for its members and contains paintings, shields and stained glass windows dating back to the 15th Century. Register now at www.pesgb.org.uk/events/presidents-evening-2/ Thank you to our sponsors P L AT I N U M

S I LV E R

HRH Geology

Sponsorship opportunities available, from Bronze at £100 to Platinum at £600 – see the PESGB website for further opportunities and all the details or email rebecca@pesgb.org.uk

28 PESGB October 2019

AN ARCHIPELAGO OF OPPORTUNITY: A S I A PA C I F I C E & P 2 4 - 2 5 J U N E 2 0 2 0 | O LY M P I A L O N D O N

C A L L F O R PA P E R S

A S I A PA C I F I C 2018 INCLUDED

45 exhibitors 10 farmout booths

#AsPac2020 @PESGB

London 2020 will build on the success of the SEAPEX conference held in April 2019 in Singapore and the PESGB-SEAPEX London 2018 event in highlighting the resurgence of E&P interest in Asia-Pacific with new ideas, new plays and new successes. The tagline â€˜Archipelago of Opportunityâ€™ is intended to reflect the diversity of new and established petroleum systems and access opportunities close to the rapidly growing energy markets across the Asia-Pacific region. The technical committee for the London 2020 SEAPEX-PESGB conference invites the submission of abstracts for this showcase event. This will again be a geoscience technical conference and preference will be given to papers that highlight successes and learnings, from the regional to reservoir scale. All submissions are welcome and we thank you in advance for your contributions.

All abstracts should be sent to andy.butler@sundagas.com by 15 November 2019

355 attendees

45%

of delegates from overseas

54 talks PESGB October 2019 29

Corporate Supporters:

Call for Abstracts – Deadline 29 February 2020

Development and Production Geology of Carbonate Reservoirs 28-29 October 2020

The Geological Society, Burlington House, Piccadilly, London Convenors: Alun Williams Equinor Andrew Barnett Shell Anna Matthews BP Björn Seyfang Equinor Ian Saikia ExxonMobil Jo Garland Cambridge Carbonates Paul Wright National Museum of Wales and Consultant Trevor Burchette Royal Holloway, University of London and CRG Ltd

Carbonate reservoirs constitute some of the most important sources of global oil and gas production. They form the world’s largest oil and gas accumulations, the world’s highest-producing fields, and have some of the longest production histories. Significant new carbonate discoveries continue to be made, and carbonates are also a source of geothermal energy or may be utilised for gas storage. Successful development of supergiant carbonate reservoirs can result in plateau production that may last for decades, giving high ultimate recovery factors. But, carbonate reservoirs can also be some of the most complex in terms of reservoir quality and heterogeneity. Many give disappointing ultimate recovery factors and some are deemed uncommercial with current technologies. Fundamental geological understanding, sufficient and appropriate geological and dynamic data, and the construction of effective models are the keys to optimising the exploitation of such reservoirs. This conference will focus on how lessons learned from more than a century of discovery, appraisal and development of carbonate reservoirs may be applied to emerging discoveries. It will bring together the experiences of diverse operators with an objective of highlighting best practices for the geological characterization of carbonate reservoirs from appraisal to production.

Potential session themes: Confirmed Keynotes: Mishrif Formation reservoirs of Rumaila Field BP

Pre-salt reservoirs of Lula Field Petrobras

• • • • • •

Excess permeability – blessing or curse? Pores vs stratigraphy – what controls dynamic reservoir behaviour? Reservoir analogues – how useful are they? Static modelling of carbonate reservoirs – how predictive can we be? Multiscale/multidisciplinary dynamic reservoir characterization – how can we integrate geology effectively? Improving recovery/revitalising old carbonate fields – adding value through geological understanding.

Planned field trips: The Carboniferous platforms of Derbyshire, led by Pete Gutteridge, Cambridge Carbonates. Zechstein carbonates of the north-east of England, led by Geospatial Research Ltd.

Call for Abstracts:

Please submit talk or poster abstract to sarah.woodcock@geolsoc.org.uk by 29 February 2020.

For further information please contact:

Sarah Woodcock, The Geological Society, Burlington House, Piccadilly, London W1J 0BG. Tel: +44 (0)20 7434 9944

At the forefront of petroleum geoscience 30 PESGB October 2019

www.geolsoc.org.uk/petroleum

Corporate Supporters:

Call for abstracts: Deadline 6 December 2019

Geopressure 2020

Managing Uncertainty in Geopressure by Integrating Geoscience and Engineering

24-26 March 2020 The Palatine Centre, Durham University, Stockton Road, Durham, UK Organising Committee: Stuart Jones Durham University Nick Pierpoint NWP Geoconsulting

24 March 2020: Field trip

Led by Richard Swarbrick and Jack Lee to North Yorkshire

25 and 26 March 2020: Conference Durham University, UK

Richard Swarbrick Swarbrick GeoPressure Consultancy Limited and Durham University

Scientific Programme Coordinators: Tom Sinclair Shell Beth Stump Chevron Stephen O’Connor Global Geopressure Advice Binh Nguyen JX Nippon Rick. Lahann Indiana University Toby Harold Repsol

The organisers invite contributions within any aspect of geopressure but are particularly interested in the various phases of pore fluid pressure prediction, modelling and overpressure evaluation to manage uncertainty during the life cycle of a well. Suggested themes and sessions include: • Pore Pressure and stress, especially complex stress regimes

• Classic case studies, including Macondo and LUSI mud volcano

• Impact of machine learning on PPFG

• Pore pressure as an exploration and prospectivity tool.

• Well engineering and PPFG • Injecting fluids underground (including CO2)

• Geopressure in mature basins – lessons learnt

• Coupling of Pore Pressure and FG including depletion and closing the drilling window

• Unconventional stress regimes

• Pore pressure in active tectonic basins

• Seal capacity and relationship with PPFG • PPFG issues in mature basins (including abandonment/decommissioning)

Further Information and abstract submissions:

To submit an abstract please send it to abstracts@geolsoc.org.uk and copy to sarah.woodcock@geolsoc.org.uk. For more information please contact sarah.woodcock@geolsoc.org.uk or visit the event website: www.geolsoc.org.uk/PG-Geopressure-2020

At the forefront of petroleum geoscience www.geolsoc.org.uk/petroleum PESGB October 2019 31

African Plate Training Week Delivered by Dr Duncan Macgregor 3 - 6 F E B R U A R Y 2 0 2 0 | P E S G B T R A I N I N G F A C I L I T Y, V I C T O R I A

Get a head start on your regional project or licence round evaluation project by getting the regional picture quickly and cheaply You may register for each regional module individually or the whole set. Each regional module consists of sections on: • •

• •

• • •

D AY 1 | M E D I T E R R A N E A N & R E D S E A S D AY 2 | N O RT H A N D N O RT H - W E S T A F R I C A D AY 3 | W E S T A F R I C A D AY 4 | E A S T A F R I C A

Tectonic setting and thermal regime Petroleum system elements (incl biogenic and thermogenic source systems) Source to sink systems Main plays and exploration history, including conjugate margin analogues Key producing and frontier Basins Current activity, opportunities and recent discoveries Exercises

For further examples of training material and presenter bio see www.macgeology.co.uk/ training-courses

Register now at www.pesgb.org.uk/events/african-plate-training-week/ £200+VAT per day or £600+VAT for the complete set PESGB October 2019

NOV 20-2 1 2019 // SC ANDIC FORUS S TAVANGER N C S - S T R A T E G Y. N O

/ /

# N C S S T R A T E G Y

KRISTINA

AMINE

EV Y

DENIS

HELLAND-HANSEN

SOUDANI

GLØRSTAD-CLARK

PA L E R M O

MARIANNE BRUVOLL

VP INTERNATIONAL

NORTH WESTERN EUROPE

SVP E XPLOR ATION

VP E XPLOR ATION

E XPLOR ATION MANAGER

OFFSHORE E XPLOR ATION

AREA EXPLORATION MANAGER

AKER BP

VÅR ENERGI

SPIRIT ENERGY

EQUINOR

TOTAL

PESGB October 2019 33

24-26 NOVEMBER 2020 BUSINESS DESIGN CENTRE LONDON

S AV E T H E D AT E

PETEX 2018 INCLUDED

116 exhibitors 1,283 sq ft of exhibition

#PETEX2020 @PESGB

34 PESGB October 2019

PETEX is the largest subsurface-focussed global E&P conference and exhibition in the UK. Complementing the 3-day technical conference, over 6000m2 of exhibition space will feature industry operators, service companies, national oil companies, financial companies and professional organisations. With a technical programme primed to discuss the latest global activity in exploration, field development, reservoir management and unconventional exploitation, and numerous opportunities for networking, PETEXâ€™s audience reflects its high quality, technical conference content. Olympia London is currently undergoing a ÂŁ1bn redevelopment; with a project of this scale and size it has taken them slightly longer than anticipated to finalise all of the moving parts, so as a result they are unable to accommodate PETEX 2020. We look forward to seeing their new facilities, but in the meantime PETEX will be returning to the Business Design Centre in Islington, a favourite amongst many of our delegates and exhibitors for its accessibility and vibrant social scene. Careful and creative planning means that we have been able to deliver a floorplan with a larger square footage than PETEX 2018 at Olympia London.

2800+ attendees

31 Countries represented

20%

of delegates from overseas 27% Senior Management & Directors

2020 HGS-PESGB Africa Conference September 15-16, 2020 Norris Conference Centers | Houston, TX

PES Est. 1964

pesgb.org.uk

Call for Abstracts January 2020 Abstract Deadline April 2020

Submit abstracts - Africa2020@hgs.org PESGB October 2019 35

5-6 MAY 2020, P&J LIVE, ABERDEEN

EMBRACING THE NEW WAVE – THE ROLE OF COLLABORATION AND TECHNOLOGY IN THE NEW ERA OF THE NORTH SEA

DEVEX is the only technical conference of its size which is focused on the full cycle of reservoir discovery, evaluation, development and recovery in the UK and provides excellent opportunities for engineers and geoscientists to come together and share knowledge. This year marks the 17th DEVEX Conference and we will focus on how new ways of working and the role of technology will shape the present and the future of the basin; what this will mean for our industry and the opportunities for new entrants or industries beyond E&P. As well as a strong technical programme, delegates will gain access to expert-led Masterclasses, Core displays, an event for Young Professionals and a Field Trip. The conference will also provide ample networking opportunities during the coffee, lunch breaks and networking session. For more information on the conference, sponsorship or exhibition opportunities, contact devex@mearns-gill.com or call 01224 646311.

DEVEX 2020 ORGANISERS

PRINCIPAL PARTNERS

36 PESGB October 2019

Abstracts are now open and will close on 31 January. We are inviting companies to submit a short 200 word abstract indicating the type of presentation preferred - either a formal 20 minute presentation or a 5 minute Techbyte presentation (Techbyte’s can be more salesoriented), on topics including, but not limited to: • Case histories on maximising production • Case histories on redevelopment of fields • Case histories on the use of new technology or novel approaches • Frontier Exploration • Advanced Recovery Mechanisms – Waterflood to EOR • Near Field Opportunities • Facilities enhancements to improve efficiency • Big Data, Artificial Intelligence and Machine Learning – practical applications.

EXPLORE AND INNOVATE WITH ESRI Join us for the ESRI EUROPEAN PETROLEUM GIS CONFERENCE October 29–30, 2019 London, United Kingdom etc. venues St. Paul’s The Esri European Petroleum GIS Conference brings together thought leaders from the oil, gas, and pipeline user community in an interactive environment that fosters exploration, collaboration, and innovation around spatially oriented petroleum workflows. Join your industry peers in London to see firsthand how geographic information system (GIS) technology can improve your bottom line by increasing communications, driving greater efficiencies, and empowering analysis and insight—for smarter decision-making. Register now at go.esri.com/PESGB19.

PESGB October 2019 37

Gaia Earth Group Gaia Earth Sciences Limited Log QC and Petrophysical Services (Wireline & M/LWD) • Tender evaluation & contract review

• Wellsite logging QC & operations’ management

• Petrophysical vendor QA audits

• Objective logging service review & follow-up

• Detailed logging procedures & risk assessments • Petrophysical & technical studies • Advanced wireline conveyance modelling

• Special projects: deep-water, HPHT, remote ops

• Wireline & M/LWD loadout QA/QC

• Training courses on wireline and petrophysics

Gaia Earth Sciences supports oil & gas companies’ requirements for safe logging operations, high-quality data and minimal rig time UK: +44 1343 830617

www.gaia-earth.co.uk

Asia-Pacific: +66 91 061 1474

info@gaia-earth.co.uk

Explore your next opportunity with a career in Geoscience Applications welcome from new and recent graduates To apply visit careers.exxonmobil.com

Applications close on Sunday 10 November 2019 38 PESGB October 2019

COMMUNITY

Members on the Move Listings correct as at 14 September 2019 Anthony Avu Echo Geoscience Management Ltd (Geophysical Advisor) to (Principal Geophysicist)

Fiona Kilbride Anadarko Petroleum Corporation (Project Geophysical Advisor) to Occidental Oil & Gas (Project Geophysical Advisor)

Mark Foster JHKI Services Limited (Managing Director) to Nedseis Geo Consultancy bv (Business Development Manager)

Giuseppe Macri CGG (Sales Geophysicist) to (Senior Sales Geophysicist)

Jenny Greenlaigh (Independent Contractor) to St Mary’s University (PGCE Student)

Nicholas Pearce Independent Consultant – Oil & Gas (Consultant Geoscientist) to Nventures (Geoscience Sales Manager)

Gillian White GNT Consulting Ltd (Director) to The OGTC (Oil and Gas Technology) (Solution Centre Manager)

New Members PESGB welcomes the following new and reinstated Members: Akinseye Aluko University of East London

Bertie Lyons Cairn Energy Plc

Dean Clark

Alistair McIntyre Anasuria Operating Company

Alice Hall RPS Energy

Chris Paton Steven Pratt IHS Markit Marcus Salter

Afolabi Morekinyo University of Aberdeen

Kyle Watts

Liam O’Flynn TGS

Shane Westlake Finder Energy Limited

Hugo Haynes John Kunka Axis Well Technology

Notices Membership Directory The PESGB Annual Directory for 2019/20 has now been published/ posted to members. If you are yet to receive one, please can you contact pesgb@pesgb.org.uk

Members on the Move Please can all Members on the Move information be sent directly to pesgb@pesgb.org.uk

PESGB October 2019 39

PES

Young Professionals

PES

K I N D LY S P O N S O R E D B Y

Young Professionals

Join our mailing list by logging into the PESGB website, edit your details and select “Young Professionals” as an interest.

Young Professionals

The PESGB YPs would like to thank CNOOC and Ireland’s Petroleum Affairs Division (PAD) for their generous sponsorship of our special interest group.

We would also like to thank IHS Markit (London) and Spirit Energy (Aberdeen) for providing high quality facilities where we are able to host our evening seminars.

pesgbyp@gmail.com

40 PESGB October 2019

Technical Seminar: ‘The Rattray Volcanics: Mid-Jurassic fissure volcanism in the UK Central North Sea’ – Ailsa Quirie (University of Aberdeen) Review by Niamh McGovern (IHS Markit & PESGB YP Committee) Alisa gave an engaging evening technical seminar on Thursday 1st August in London on her PhD research on the Rattray Volcanics within the UK Central North Sea. The talk covered previous research particularly that the Volcanic province was sourced from central volcanoes. Alisa showed that through her re-interpretation using 3D seismic and well data, that these volcanic centres were absent, and the Rattray Volcanics were sourced in fissure eruptions from linear vents. She also explained that the pre-Middle Jurassic sedimentary sequences beneath the Rattray Volanics are more extensive than previously thought and that non-intruded reservoirs and source rocks in the Rattray area have been underestimated. We sincerely thank Alisa for giving an excellent technical seminar, IHS Markit for allowing us to use their facilities, and CNOOC International for their continued support of the PESGB Young Professionals.

PESGB Young Professionals

facebook.com/pesgbyp

@pesgbyp

pesgbyp

COMMUNITY

REVIEWS

London YP Gumball Challenge Review by Carl McDermott & Connor Sullivan (PESGB YP Committee) On August 15th we launched the first ever ‘PESGBYP Gumball Challenge’! This event saw four teams of adventurous young professionals complete a series of challenges in exchange for points, taking them from Green Park tube station to the PESGB offices near Victoria. All the while these resourceful combatants raced against the clock (and an increasing ridiculous series of photo opportunities) to fight for the most important prize of all, tiny trophies and plastic ‘Winners’ medals. There were trials of course. Teams were asked to transport, protect and decorate their egg-quisite mascot, chase down ‘Victoria’ and get in touch with nature to name a few. However, there could only be one winner. Congratulations to ‘Gneiss Guys Finish Last’ for a game well played and for not living up to their name-sake. After the event attendants were able to trade stories and pictures from their own adventures while also extending their network. Thank you to all those who attended, your antics kept us amused for hours! “I attended the YP event along with some colleagues from CNOOC. The gumball challenge was great fun and must have required a significant amount of effort from the organisers to put together. It was good chance to meet and network with other subsurface professionals in an open and relaxed environment. Thanks to everyone involved, I shall definitely be attending more of the events in the future!” Matt Haythornthwaite (CNOOC)

UPCOMING EVENTS

Everyone is welcome – these events are run by YP’s but are for all PESGB members LONDON

PESGB, AAPG & EAGE YPs Autumn Networking Event Thrsday 17 October 2019, 6.30pm The White Hart, 29 Cornwall Road, London SE1 8TJ The Young Professionals of the AAPG, EAGE and PESGB invite you to our Autumn Networking Event. Our annual event is designed to help young professionals in the Oil and Gas industry begin to develop their network and meet other professionals from across the industry. We hope you can join us for this excellent opportunity to grow your network by meeting new, like-minded people and catching up with old friends! www.eventbrite.co.uk/e/aapg-eage-and-pesgb-autumn-networking-event-tickets-56115584223 PESGB October 2019 41

PES D AT E S F O R Y O U R D I A R Y | V I S I T P E S G B . O R G . U K T O R E G I S T E R

Machine Learning

Old Timers

Facies Classification and Seismic Inversion to Improve Predictions

Tuesday 15 October 2019, 11am PESGB Offices, Victoria

With Daria Lazareva and Shervin Rasoulzadeh, CGG GeoSoftware

The Old Timers have had three positive initial meetings. We have enjoyed robust conversations about a wide variety of geology and petroleum geology subjects, from the UK and around the world, some current some historical. You are invited to come and join the conversation. Do come prepared with what you would like to discuss. After an hour or so of debate we shall adjourn to a local eatery for lunch.

Thursday 3 October 2019, 6pm PESGB Offices, Victoria As data becomes more and more abundant, machine learning is rapidly becoming a standard technology in the oil and gas industry. Machine learning drives more effective methods and introduces tools and theories for discovering, modeling and extracting patterns and relationships embedded in large datasets. Companies can determine reservoir properties more accurately and more quickly using a new generation of analytics and prediction techniques from machine learning. We continue to expand on our machine learning technology. Today, machine learning can address complex petrophysical and reservoir engineering challenges by automating mundane routine tasks such as modeling missing log curves and use data clustering for facies classification essential for seismic reservoir characterization or automatically identifying and flagging poor-quality log curves in a project. Users can also take traditional reservoir characterization approaches a step further by deriving actual reservoir properties by predicting 3D volumes that geophysicists and geologists need. This two-part presentation focuses on machine learning for petrophysical and geophysical data. The potential for machine learning to improve understanding of wells, reservoir and producing fields is virtually unlimited, and to some extent, it all begins with well log data. For data clustering, we are using environmentally corrected, normalized and depth-shifted data to ensure valid interpretation results. We also discuss leveraging machine learning for seismic reservoir studies using deep neural networks. Deep neural networks require large amounts of seismic and well data. In geoscience studies, the number of wells that has been acquired in a prospective area can be limiting and acquiring new well data can be expensive. We show how to augment the lack of well data, generate a multitude of synthetic data and train deep neural networks to improve the reservoir prediction. We do this by the use of Rock Physics Models (RPMs), â€œwhat ifâ€? scenarios (e.g. model changes in porosity, saturation, and lithology) and detailed statistical analysis based on real measurements. As companies seek to transform their work practices, processes and workflows to ultimately streamline and improve operations, machine learning strengthens the necessary synergy for multi-disciplinary collaboration. 42 PESGB October 2019

Offshore Africa A Return to Frontier Exploration With Emma Woodward & Jimmy Boulter

Thursday 17 October 2019, 6pm PESGB Offices, Victoria 2020 promises to be an exciting year for oil and gas exploration in Africa, with a number of high impact newfield wildcat wells planned across multiple basins. This presentation will look at major recent discoveries and key upcoming wells, trends in acreage acquisitions, as well as legislative changes and other above ground risks that are helping/hindering IOCS activity; focusing on the frontier areas that will be the driver of future industry growth on the continent.

UK Onshore Exploration Tuesday 22 October 2019, 6:30pm Fox on the Green, Islington

Executive Council 2020 Elections

COMMUNITY

It's that time of year again - election time. That's right; you will now be able to have your say about the future of our organisation and vote in our council election survey! You will be able to do this today through a link in your memberâ€™s page, located in the 'My Account' area. Many positions within our council are now up for contest as the terms of many of our current board members are coming to an end. They all did a fantastic job and, despite the condition of the industry, we believe that due in a large part to their hard work and dedication our organisation is stronger than ever before. The selection of nominees we have for the 2019 council seems to be just a promising as the past yearâ€™s. We have excellent candidates and everyone here at PESGB is sure that, whatever the outcome of the election, we will be in safe hands. Please take the time to meet our candidates through the links to below. We will announce the results of the election as soon as possible and will be sure to tell you all about our new council. Thank you in advance for taking part!

Visit the PESGB website for more information about each nominee

V O T E T O D AY ! PRESIDENT ELECT

Julian Bessa

Julie Branston

YP DIRECTOR

Vikesh Mistry

Holly Marie Owen

E D U C AT I O N A N D T R A I N I N G

Steve Pickering

Gavin Elliot

TREASURER

Graham Robertson

Guy Ward

OUTREACH DIRECTOR

Richard Milton Worssell

ABERDEEN ELECT

Cliff Lovelock

Nicholas Cope

COMMS.DIRECTOR

Dave Moseley

PESGB October 2019 43

PES

Sustaining Sponsors Thank you to the following Sustaining Sponsors for their support of the PESGBâ€™s objective of education into the scientific and technical aspects of petroleum exploration and encouraging the advancement of petroleum exploration in Great Britain.

Adrok Ltd

Apache

AustinBridgeporth

CGG

Chevron North Sea Limited

CNOOC

ConocoPhillips (UK) Ltd

DataCo

Deering Petrophysical Ltd.

DrillingInfo

Edison E&P UK Ltd.

Envoi Ltd

Equinor Production UK Ltd

ERCE

ExxonMobil

Gaia Earth Sciences Ltd

GETECH

ikon Science

ION

Integrated Reservoir Solutions Ltd

Ithaca Energy (UK) Ltd

Katalyst Data Management

Merlin Energy

OPC

Onefix Media

OvationData Limited

PetroTrace

PGS

44 PESGB October 2019

Become a Sustaining Sponsor K I M M E R I D G E | £ 2 , 0 0 0 + VAT

Polarcus

Premier Oil plc

RISC Advisory

RPS

Your company logo featured in our monthly magazine and in the directory 20% off the media kit prices for your advertising in the PESGB Magazine One half page advert per annum (worth over £800) Sustaining Member collaborative sponsorship of the PESGB reception at 3 large industry events per annum. Sustaining Member collaborative sponsorship of the PESGB reception desk at 9 Evening Lectures at the Geolsoc Sustaining Member collaborative sponsorship of the PESGB Flagship event; The Stoneley Lecture, in venues nationally Free Job Adverts in the PESGB Magazine and on the PESGB Website B R E N T | £ 1 6 0 0 + VAT

Shearwater GeoServices

Shell UK Ltd

Siccar Point Energy Limited

Spirit Energy

Your company logo featured in our monthly magazine 20% off the media kit prices for your advertising in the PESGB Magazine One half page advert per annum (worth over £800) Sustaining Member collaborative sponsorship of the PESGB reception at 3 large industry events per annum. Sustaining Member collaborative sponsorship of the PESGB reception desk at 9 Evening Lectures at the Geolsoc Free Job Adverts in the PESGB Magazine and on the PESGB Website F O R T I E S | £ 9 0 0 + VAT

SummitExploration&ProductionLtd

TOTAL E&P Ltd

Westwood Global Energy Group

Xodus Group

Your company logo featured in our monthly magazine and in the directory 15% off the media kit prices for your advertising in the PESGB Magazine One half page advert per annum (worth over £800) in an issue of your choice. Free Job Adverts in the PESGB Magazine and on the PESGB Website F U L M A R | £ 5 0 0 + VAT

Zennor Petroleum Zennor Petroleum

Your company logo featured in our monthly magazine and in the directory 15% off the media kit prices for your advertising in the PESGB Magazine Free Job Adverts in the PESGB Magazine and on the PESGB Website PESGB October 2019 45

Training Courses 2019/2020

Operations Geology Drilling Technology Formation Evaluation

Course Dates WO1: Introduction to Drilling & Wellsite Geology

G2: Operations & Wellsite Geologist

October 7th - 11th Reading January 13th - 17th Reading March 9th - 13th Reading

November 4th - 7th Reading December 9th - 12th Reading February 10th - 13th Reading April 6th - 9th Reading

FE1: Basic Log Interpretation October 14th - 16th Reading January 27th - 29th Reading March 23rd - 25th Reading

P1: Formation Pressure Evaluation November 11th - 13th Reading February 24th - 26th Reading April 27th - 29th Reading

C1: Best Practices in Core Handling & Analysis October 21st -23rd Reading

Measured Distance

Depth of Investiga tio

Boundary/Fluid Contact

Distance to Boundary calculation DOI = tan θ MD

MD =

DOI tan θ

Westpoint House Pavilion 2, Prospect Park Prospect Road Arnhall Business Park Westhill Aberdeenshire AB32 6FJ

3 Fortuna Court Calleva Park Aldermaston Reading U.K. RG7 8UB

wwwwww.stag-

Contact:

martin.saunders@stag-geological.com

Como Corporate Centre Suite 22, 11 Preston Street Como WA 6152 West Australia

+44 (0) 118 982 0151

www.stag-geological.com/training 46 PESGB October 2019

Make Better Decisions

on the Angola Namibe 2019 Licensing Round

Angola

In collaboration with:

Blocks in Licensing Round GeoStreamer 3D GeoStreamer 2D

MultiClient 2D and 3D depth data provide stunning images of pre and postsalt plays. Fast-track your bid evaluation for the Namibe licensing round opening on 3 October 2019 with this essential dataset and benefit from our extensive technical experience in the region. Arrange a data show and prospectivity review: amme.info@pgs.com

A Clearer Image | www.pgs.com/DataLibrary

PESGB October 2019 47

PES Linda Wang, Technical Research Principal, IHS Markit

An overview of the largest shale gas field in China The Fuling shale gas field (alternatively Jiaoshiba shale gas field), with proven gas in-place of greater than 600 Bcm (21 Tcf), is the first large scale shale gas producing field in China. The field is operated by one of the national oil companies, China Petroleum & Chemical Corp (Sinopec), and has produced a total of about 21.45 Bcm (757 Bcf) of shale gas as of 2018. The Fuling field is located in the Fuling block, Chongqing Municipality in the Sichuan Basin. The discovery well, Jiaoye 1HF (JY1HF), was drilled in the northern part of the Jiaoshiba structure, which is situated in the Chuandong fold belt at the south-east margin of the basin, and bounded by the Qiyue Mountain Fault, west of the basin. Jiaoye 1HF, which was sidetracked from the vertical well Jiaoye 1 (JY 1), was drilled to a TD of 3,654 m, and had a horizontal section of 1,008 m. Jiaoye 1HF tested a high flow rate of over 203 Mcm/d (7.2 MMcfg/d) from the marine shales of the Silurian Longmaxi and Ordovician Wufeng formations after fracturing. EXPLORATION HISTORY Geological surveying in the Jiaoshiba area started prior to 2000, with around 417 km of 2D seismic data acquired. This lead to the definition of the Jiaoshiba structure. Structure and reservoir evaluation studies were then conducted in 2006, but were mostly focused on conventional gas resources and plays. Initial results indicated poor conventional resource potential. In 2009 Sinopec started substantive shale gas resource studies in the area. The initial evaluation of shale gas potential showed a nearly 4,000

km2 area with resources of more than 2,000 Bcm (71 Tcf). Sweet spot depth was less than 4,500 m. Newfield wildcat Jiaoye 1 was selected in 2011 to test the marine shales in the Jiaoshiba structure. Jiaoye 1 was spudded on 14 February 2012 and reached a TD of 2,450 m in the MidOrdovician Shizipu Formation. JY 1 encountered good gas shows in the Silurian Longmaxi shale horizon during drilling. Wireline logs, gas data and core samples indicated 89 m of shale gas pay. Around 38 m of good quality shale gas intervals with gas content up to 5.19 cm/t at the

Figure 1. Comprehensive Assessment Graph of Wufeng-Longmaxi Formation Shale Reservoirs in Well JY1 (Modified after Bao, 2014) 48 PESGB October 2019

lower part of the Wufeng â€“ Longmaxi formations were encountered (GUO Tonglou, et al., 2014). To further evaluate and confirm shale gas productivity, Jiaoye 1HF was then drilled in 2012 and it encountered good gas shows while drilling the horizontal section (see Figure 1). Total hydrocarbon value was up to 31% in a 383 m interval between 2,661 and 3,044 m. A 15-stage hydraulic fracturing work was conducted at 2,646 â€“ 3,654 m (vertical depth 2,385 - 2,415 m) and it tested a high flow rate of 203 Mcm/d (7.2 MMcfg/d) via a 14 mm choke under wellhead pressure of 6.8 Mpa

N E W S F E AT U R E

(SINOPEC-Xinan, 2015). The Wufeng – Longmaxi marine shales encountered by the discovery well had high quality, widespread distribution, thick, high abundance of organic matter with moderate burial depth, making it ideally suited for large-scale production. Following the discovery well, enhanced exploration work was quickly carried out to appraise the Wufeng – Longmaxi shale formations in the northern part of the structure. About 600 km2 of 3D seismic survey was acquired, and three appraisal wells Jiaoye 2HF, Jiaoye 3HF and Jiaoye 4HF were successfully drilled, and tested high gas flow rates of 340 Mcm/d (12 MMcfg/d), 120 Mcm/d (4 MMcfg/d), and 260 Mcm/d (9 MMcfg/d) respectively. This resulted in getting an approved 106 Bcm (3.8 Tcf) of gas in-place, with recoverable resources of 27 Bcm (942 Bcf) within an area of 106 km2 covered by the Jiaoye 1 to Jiaoye 3 well vicinity (see Figure 2). Further exploration then extended to the middle and south of the structure. A 3D seismic survey covering a 270 km2 area was acquired in February 2015. The survey focused on the south area to define the Longmaxi shale “sweet spot” and providing important references for the next exploration and development targets. Jiaoye 5, Jiaoye 6, Jiaoye 7, Jiaoye 8, and Jiaoye 9 wells were then drilled successfully in the middle, south and periphery of the structure (see Figure 2). These wells booked an additional 494 Bcm (17.5 Tsf) of gas in-place and resulted in a total gas in-place of 600 Bcm (21 Tcf) for the entire field.

1. GEOLOGICAL FEATURES Structure and traps: The field is understood to be stratigraphically trapped, with gas present in good quality shale intervals. The Jiaoshiba structure is a faulted anticline located in the Wanzhou Synclinorium, and has experienced multi-phase tectonic movements. The main body of the structure trends towards the northeast with a gentle dip of less than 5 degrees, and was controlled by both northeast trending faults and nearly north-south trending faults. The tectonic cross-section shows the shale formations as continuous layers across the majority of the structure.

Figure 2. Wells locations and distribution of faults in the Wufeng – Longmaxi Formation of the Fuling field (Modified after Guo, Hu, Li, et al, 2017)

PESGB October 2019 49

PES An overview of the largest shale gas field in China (cont.)

Figure 3. Shale gas reservoir section of the Wufeng – Longmaxi Formation (Modified after Wang, 2015)

Shale reservoir, shale source rock and its maturity: Comprehensive assessment revealed the total thickness of gas-bearing shales in the Wufeng - Longmaxi formations range from 80 to 100 m, including about 35 to 45 m of highquality marine hshales. The bottom of the shale gas layers was buried to a depth of between 2,250 and 3,500 m, with a pressure coefficient of 1.55 and geothermal gradient of 2.73 degrees C/100 m. Average porosity was around 5% and permeability was about 215 mD (GUO Xusheng, et al., 2017). The Longmaxi Formation consists of a lower section of black graptolite shales and sandy shales, and an upper section of greyish-green shales and sandy shales. The black shales of the lower section were characterized 50 PESGB October 2019

by high abundance of organic matter, high quality thick pay, widespread distribution, good kerogen type and high maturity. The Total Organic Carbon (TOC) content of the Wufeng - Longmaxi black shales vary between 0.5 and 5.9%. Most are highly mature or over-mature with Vitrinite Reflectance (Ro) ranging from 2.4% to 3.1%, with an average of 2.7%. Organic material was dominated by Type I kerogen coming from plankton and algae. About 40 m of high-quality shales with TOC of greater than 2% was identified in the lower part of the Wufeng – Longmaxi formations (Figure 1) (GUO Xusheng, et al.,2017). The shale gas produced from the Jiaoshiba field is sweet with methane content greater than 98%.

2. DEVELOPMENT AND PRODUCTION The development decision was made based on the results from the trial production in Jiaoye 1HF and the pilot development zone within the major shale gas resources in Jiaoshiba block in Fuling. Jiaoye 1HF started trial production in January 2013, with output levels between 45 Mcm/d (1.6 MMcfg/d) and 70 Mcm/d (2.5MMcfg/d). Stabilized average production of 60 Mcm/d (2.1 MMcf/d), with stabilized tubing pressure of 20 Mpa, was achieved for half a year. Sinopec has also implemented a series of experimental wells tests in the pilot development zone, such as a ‘star shape’ well pattern with well spacing of 1,000 m; horizontal drilling between 1,000 and 2,100 m;

N E W S F E AT U R E

fracking; constant pressure and constant production testing to prepare for the development of the Fuling field. In September 2013, the National Energy Administration officially approved the establishment of the Fuling National Shale Gas Demonstration Area which had an area of 7,307.77 sq km. Subsequently, the construction of the demonstration area started in November 2013. About 20 experimental wells have been drilled by early 2014 in the pilot development zone, the testing production volume per well averaged at 337 Mcm/d (12 MMcfg/d) with the highest volume at 550 Mcm/d (19 MMcfg/d) (Sinopec, 2014). On 28 November 2013 the Chinese government approved the Fuling shale gas field development plan â€“ the Phase I development plan, which was based on the knowledge gained from the implementation of the development experimental wells tests and the result of the pilot evaluation in 2013. Sinopec planned to develop 341 Bcm (12 Tscf) of shale gas resources in two phases, pushing forward to reach its goal of building 10 Bcm (353 Bcf) of production capacity per year by 2017. Phase I of the project mainly focused on the development of the northern part of the field. This included drilling 253 new shale gas wells from 63 drilling platforms, and the construction of new shale gas collection and transmission facilities. The production capacity was expected to be 5 Bcm (177 Bcf) per year of shale gas. The project was brought into commercial production in March 2014, and

reached the targeted capacity by the end of 2015. Phase II of the project focuses on drilling programs in the middle and southern parts of the field (Jiangdong, Pingqiao, Baitao and Baima blocks) and builds an additional 5 Bcm (177 Bcf) per year of production capacity. Around 300 new wells were to be drilled from 90 drilling platforms. Development assessment work for Phase II started in late 2014. Seven appraisal wells were drilled to assess the resource scale, extension and productivity potential of the shale gas outside of the Phase I development area. Jiaoye 69-2HF, located in the Fuling Jiangdong village, was the kick-off well for the Phase II project. It was spudded in Feb 2015 and had a TD of 5,642 m. It tested at a high shale gas flow rate of 146 Mcm/d (5.2 MMcfg/d) from a horizontal section of 1,574 m. The well tested shale gas buried deeper than 3,500 m and has proven more exploitable resources in the Jiangdong region. As planned, 10 Bcm (353 Bcf) of shale gas production annual capacity had been built in the Fuling shale gas field by the end of 2017, with 305 wells on production (Dazhong Dong, et al. 2018). As of end-2018 the field achieved an annual production capacity of 10.503 Bcm (371 Bcf), with approximately 386 wells on production. The addition of 503 MMcm (17.8 Bcf) of annual shale gas production capacity was built in 2018. The gas produced from the field was initially compressed to LNG for sales locally to the Chongqing market. Gas was then later delivered to other

provinces and cities though new shale gas pipelines constructed in the Sichuan Basin, feeding into Sinopecâ€™s existing gas truck lines. 3. LOOKING FORWARD The large-scale commercial development of the Fuling shale gas field benefits from the breakthrough of key technologies. At present, China has accumulated the relevant technologies for the marine facies shale gas development shallower than 3,500 m. Compared with the initial stage of the development, the drilling cycle of the Fuling shale gas field is shortened by more than 30% and fracturing efficiency is increased by more than 50%. Sinopec is planning to further grow the production in the Fuling gas field with more wells drilled and addition of reserves. The company is striving to produce 6.3 Bcm (222 Bcf) of shale gas in 2019, up from 6.02 Bcm (213 Bcf) in 2018, and further increase the production to 7 Bcm (247 Bcf) by 2020. An additional 100 Bcm of proven gas in-place within two or three years is targeted. Technology advancement is also key to effectively produce the deeper shale gas in the area (more than 3,500 m burial depth) once the development of the shallower shale units become more mature. More than half of the shale gas resources in the wider Sichuan Basin are also buried deeper than 3,500 m. Sinopec has ambitious plans to grow shale gas production in the Fuling field during the coming years.

For further information contact: Adrien Charaudeau, IHS Markit Adrien.Charaudeau@ihsmarkit.com

PESGB October 2019 51

PES International News ARGENTINA Wintershall Dea has secured a new partner for the Aguada Federal and Bandurria Norte blocks in the Vaca Muerta fairway. ConocoPhillips has signed a sales and purchase agreement for the joint development of both blocks, bringing its expertise from the United States’ unconventional plays, where it is active in the Bakken, Eagle Ford and Permian. Under the terms, the Houston-based company will acquire a 45% interest in the 97 sq km Aguada Federal block, with the remaining interest held by Wintershall Dea (45%) and Gas y Petróleo del Neuquén (10%). In the 105 sq km Bandurria Norte block, interest will be split 50:50 between the two international companies, with Wintershall Dea retaining operatorship of both blocks. The German company has been running pilot projects since 2015, and production testing is already underway. No consideration was disclosed for the transaction, which is expected to close in 2019, pending regulatory approval. Although the deal marks ConocoPhillips’ entry into the Neuquen Basin, the company is already present in Argentina, partnered with Chilean ENAP in the El Turbio Este exploration contract in the Austral Basin. Equinor and YPF have signed an agreement to jointly explore the CAN 100 block in the northern deepwater Argentina Basin. The tract covers 14,770 sq km in water depths of 500 – 4,000 m. The first four-year exploration period began in May 2019 when YPF was awarded 100% interest, of which 50% will be transferred to Equinor. The two companies are already partnered in the CAN 102 and CAN 114 blocks in the same area, which were awarded following Offshore Round 1 held earlier this year. Equinor has been steadily building its Argentinean portfolio, 52 PESGB October 2019

adding interest or operatorship in a total of seven blocks in the Argentina, Colorado, Malvinas and Austral basins after Round 1, in addition to its holdings in the onshore Neuquen Basin. AUSTRALIA Woodside has launched the production phase of the Greater Enfield project offshore Western Australia. First oil was achieved on 25 August 2019, with the Laverda, Norton over Laverda and Cimatti accumulations linked by 30-km subsea pipelines to the “Ngujima-Yin” floating production storage and offloading (FPSO) vessel, located over the Vincent field. The project comprises 12 subsea wells – six for production and six for water injection – and total 2P reserves are estimated at 69 MMboe. The development required an investment of USD 1.9 billion and is expected to yield around 40,000 b/d. Woodside operates the Greater Enfield project with a 60% interest, with partner Mitsui holding the remaining 40%. The fields are situated in WA-59-L and WA-28-L, which cover a combined area of 400 sq km in the deepwater part of the North Carnarvon Basin. BRAZIL The Agency of Petroleum, Natural Gas and Biofuels (ANP) has approved BW Offshore’s status as operator and the transfer of equity in the Maromba heavy oil field in the southern Campos Basin. The company now holds 100% interest in the field, which triggers the first payment of USD 30 million to former owners Chevron and Petrobras, with a further USD 85 million to be paid in two stages by first oil or three years after the commencement of drilling activities, whichever comes first. Discovered in May 1980, Maromba was delineated by nine wells and

declared commercial in December 2006. The field was originally planned to come online in 2015 via subsea wells tied back to a Floating Production Storage and Offloading (FPSO) vessel with a capacity of 60,000 b/d, but the project ran into delays and was never implemented. Recoverable resources are estimated at 100 - 150 MMbbl and there is upside potential for over 1 Bbbl of oil in place. BW Offshore intends to deploy one of its existing FPSOs to Maromba as part of a phased development and apply the same procedure that was used to successfully bring the Dussafu project on stream in Gabon. CAMBODIA On 13 August 2019, Canada’s Angkor Gold announced that the Royal Government of Cambodia has approved the award of Block VIII, which covers 7,300 sq km across the Kompong Som and Phu Quoc basins in southeast Cambodia (mostly onshore). Angkor will now negotiate a Production Sharing Agreement (PSA) to pursue oil and gas exploration in the licence, its first in the country (although it holds several mining leases). Block VIII is undrilled and the Kompong Som Basin is a frontier area, but Angkor Gold stated that the regional geology and thermal maturity suggests potential for oil. Potential prospective exploration targets in the area include continental Cretaceous sediments and Permian carbonates. There is no commercial hydrocarbon production in Cambodia, but the government has been seeking to promote the development of the country’s hydrocarbon resources and notably cooperated with PGS in a 2,080-sq km 2D seismic campaign in 2007, which covered parts of Block VIII.

N E W S F E AT U R E

GUYANA In mid-August, Tullow Oil became the second operator to make a large oil discovery offshore Guyana. The Jethro-Lobe 1 wildcat was drilled in 1,350 m of water to a total depth of 4,400 m by the “Stena Forth” drillship in the eastern part of the Orinduik block, encountering 55 m of net high-quality oil pay in excellent Lower Tertiary sandstone reservoirs. Recoverable reserves are reportedly commercial and within range of the initially estimated 250 MMbbl, to be confirmed by further appraisal work. Hoping to build on this success, the Anglo-Irish company has spudded the Joe 1 wildcat in the western part of the block, targeting additional P50 resources of 150 MMboe in a shallower Upper Tertiary target. Interest in the licence is split between Tullow Oil, operator with 60%, and partners Total (25%) and Eco Atlantic (15%). INDONESIA Following the Conventional Oil and Gas Bidding Second Round 2019, Eni and partners have been officially awarded the West Ganal production sharing contract (PSC) in the Kutei Basin. The block covers 1,129 sq km in the Makassar Strait offshore East Kalimantan and contains the Maha discovery, with in-place gas resources estimated at 600 Bcf. The block was offered in the Conventional Oil and Gas Bidding First Round 2019 and received bids from a Pertamina/Eni consortium and from Neptune Energy, but was ultimately not awarded and was re-offered in the next round. Interest will be divided between Eni, operator with 40%, Pertamina (30%) and Neptune Energy (30%). The three companies are already partnered in the adjacent Muara Bakau block, containing the producing Jangkrik field, allowing for near-field development synergies. Eni is already moving ahead with

development of the Merakes discovery in its operated East Sepinggan PSC, also adjacent to the newlyawarded West Ganal block and taking advantage of existing infrastructure at Jangkrik. JORDAN Questerre Energy has been invited by the Jordanian Ministry of Energy and Mineral Resources (MEMR) to apply for a concession agreement for an oil shale development project. The announcement follows completion of a feasibility study conducted over three blocks in the southern Isfir Al Mahatta and Jafr areas covering a total area of 264 sq km. The company expected to commence negotiations on fiscal and other terms later in the third quarter and will continue to hold exclusive rights over the acreage in the meantime. Questerre has partnered with engineering firm Hatch and Red Leaf Resources on the project, with the aim of improving returns using Red Leaf’s “EcoShale” process. Studies so far have led to unrisked estimates of 7.8 Bbbl of in-place resources, while Hatch has designed plans for a 50,000 b/d development, coupled with a refinery with capital and operating costs of around USD 40 per barrel. MALTA Edison has signed an Exploration Study Agreement for three blocks jointly covering an area of 6,400 sq km in the Pelagian Basin. The company will have one year to conduct geological and geophysical studies on Blocks 1, 2 and 3 of Area 3 north of Malta, with the option for a two-year extension. The acreage lies in 100 - 1,600 m water depths and encompasses seven wells, of which none encountered commercial hydrocarbons. The last well was abandoned with gas shows by Eni in June 2002: Lampuko 1 targeted the same Upper Triassic and/or Lower Jurassic

carbonates that form proven reservoirs in southeastern Sicily and ended at a depth of 4,115 m. The Vega oil field, in production since August 1987 and operated by Edison, sits only 20 km away. No commercial discoveries have been made offshore Malta so far and the only valid Production Sharing Agreement is held by Heritage Oil, covering Areas 2 and 7. OMAN After signing a head of agreement early in 2019, Eni and BP have officially secured a 50:50 split in the Block 77 exploration and production sharing agreement (EPSA), with approval from the Ministry of Oil and Gas. The block is situated 30 km east of the BP-operated Khazzan field, covering some 2,700 sq km and containing a number of existing discoveries and fields including Qarn Alam, Ghaba North and Saih Nihayda Southeast. Eni will operate during the exploration phase. The Italian company was officially awarded its first Omani asset in November 2017 with Block 52, covering nearly 100,000 sq km off country’s southern coast. A 2D/3D seismic survey was completed over Block 52 in the first quarter of 2019. Also in early 2019, Eni was awarded the onshore 8,522-sq km Block 47, prospective for tight gas. Oman is the largest non-OPEC producer of oil and condensate in the Middle East, with a current output of 856,000 b/d, along with 4.4 Bcf/d of gas, and the government has shown itself keen to attract foreign investment. RUSSIA Following the go-ahead by the Federal Antimonopoly Service (FAS), Repsol has acquired a 50.1% interest in Gazprom Neft’s Karabashskiy-6 unit, owner of six exploration licences in the Ural-Frolov Province. The Spanish company is now present in the Karabashskiy-17, -18, -19, -25, PESGB October 2019 53

PES -26 and -27 blocks, adding a gross area of 1,600 sq km to its existing portfolio in the Khanty-Mansiysk Autonomous Okrug (Western Siberia). Through the Eurotek Yugra joint venture, Repsol already operates the Karabashskiy-1, -2, -3, -9, -78 and -79 blocks, as well as the Kileyskiy licences along with Gazprom Neft. Karabashskiy-1 and -2 encompass the 2013 Ourinskoye field (later renamed R.Yu.-Ervier), with recoverable reserves of 245 MMbbl of oil and 300 Bcf of gas. At the end of 2018, the two parties also acquired Moscow-based ASB Geo, the parent company of Berezovskoye 10, Karabashskoye 10 and Karabashskoye 83 owning three blocks with a total resource potential

of 88 MMbbl of oil and 440 Bcf of gas. The latest transaction further strengthens their partnership. TRINIDAD AND TOBAGO Fresh off a successful exploration campaign, BHP reported on 8 August that it has approved a total USD 500 million investment (USD 283 million net to the company) for the Ruby oil and gas project in the Block 3(a) development area, located some 40 km offshore east Trinidad and Tobago. The project will involve five development wells that will produce from the Ruby and Delaware reservoirs, to be tied back to existing processing facilities. The overall development has estimated recoverable resources

of 13.2 MMbbl of oil and 274 Bcf of gas. First production is expected in 2021, adding some 16,000 b/d of oil and 80 MMcf/d of gas output. Interest in Block 3(a) is held by operator BHP (68.46%), Heritage Petroleum (20.13%) and state company NGC (11.41%). The Australian company is present in nine licences offshore Trinidad and Tobago, notably operating the Greater Angostura gas and oil field with a 45% interest.

PESGB International News is sponsored by IHS Markit. For further information please contact Tiziana Luzzi Arbouille: tiziana.luzzi@ihsmarkit.com

Asia-Pacific News AUSTRALIA Operator Strike Energy (50%) has drilled the West Erregulla-2 well, in EP469 in the North Perth Basin, more than 5,017m deep (approx. 16,460 ft), making the well Australia’s deepest onshore well. Strike announced it had intercepted the early Permian, High Cliff sandstones at 4,928m (16,168 ft) and had observed extended drilling breaks throughout the formation. Carnarvon Petroleum reported it had secured the “next phase” for the re-development of the Buffalo oil field after it signed a Production Sharing Agreement with Timor Leste last Friday. The Buffalo field lies in WA523-P offshore northern Western Australia in the Timor Sea. The field was previously owned by BHP, which commenced production in 1999. It produced 20.5 MMstb of undersaturated oil from four production wells, before being decommissioned in 2004. It is currently estimated to hold 2C resources of 31 MMBoe. Until recently, the permit sat exclusively in Australian commonwealth waters. The federal government and 54 PESGB October 2019

government of Timor Leste have now ratified the Maritime Boundary Treaty and the permit is split across both countries boundaries, and the filed requires a separate PSC between Carnarvon and Timor Leste. Woodside is proposing to drill and develop four production wells as part of Phase 2 of its Julimar Development in the Carnarvon Basin, off the coast of Western Australia. Water depth in the permit area is up to 220m (721 ft). The Julimar development project includes the development of the Julimar and Brunello natural gas fields which are the largest gas discoveries made by Apache with combined recoverable gas reserves estimated to be in excess of 2.1 Tcf. The proposed activities, outlined in Woodside’s environmental plan currently under consideration by the regulator, will go ahead within production licence WA-49-L, approximately 186 km (approx. 115 miles) offshore from the major industrial port of Dampier. Phase 2 will develop gas from the Julimar reservoir in the Triassic Mungaroo formation as a subsea tieback to the

existing Brunello subsea infrastructure. Apache Julimar, the Australian subsidiary of Apache Corporation, was the operator of the project and held 65% interest until May 2014. Apache’s equity ownership in Apache Julimar was transferred to Woodside Petroleum under a sales agreement effective from 30 June 2014. The remaining 35% interest is held by Kuwait Foreign Petroleum Exploration Company. Carnarvon Petroleum reported its Roc South-1 well near the recent Dorado oil discovery in the Carnarvon Basin, off the coast of Western Australia has come up dry. Roc South-1 was a late addition to the three well appraisal campaign at Dorado and aimed to see if there were additional hydrocarbons which could be tied into the Dorado field development. INDONESIA Eni (40%) has been awarded operatorship the West Ganal exploration block in the Kutei Basin in offshore Indonesia by the ministry of energy and mineral resources, along

N E W S F E AT U R E

with its partners Pertamina (30%) and Neptune (30%). West Ganal is a new gross split production sharing contract, covering an area of about 1,129sq.km (approx. 436 sq miles), linking the Eni-operated Muara Bakau and East Sepinggan PSCs, in the Makassar Strait offshore East Kalimanta. The block includes the Maha discovery which is estimated to hold more than 600 Bcf. MONGOLIA Elixir Energy, with headquarters in Adelaide has contracted local drilling company Erdenedrilling for its Nomgon IX Coal Seam Gas (CSG) acreage in the South Gobi desert hiring. Elixir is hoping to register the nation’s first gas discovery. The drilling contract will see Elixir drill two fully tested CSG wells with the option for a third, with Elixir planning a late September or early October spud. PAPUA NEW GUINEA

Papua New Guinea’s petroleum minister is considering redrawing its agreement with Total on the Papua LNG project if a government review finds its terms unfavourable. Total is operator and plans a two-train expansion in tandem with the ExxonMobilled PNG LNG operation which plans a one train addition. Together the two projects will double the nation’s LNG export volumes at a cost of over US$13 billion. Many in the government believe the original deal did offer enough local benefits but PNG wants to increase the government’s share of resource revenue and is the first time the new government has made comments that it is open to a lengthy renegotiation to the agreement. THAILAND Australian independent E&P company Tap Oil and Abu Dhabi based Mubadala Petroleum have completed their development drilling programme in the Manora field in the Gulf of

Mexico Thailand ahead of schedule and on budget, with multi rate testing carried out on both wells before moving into long term production. Both the MNA-24H and MNA-23H horizontal development wells were targeting undeveloped reserves in the 300 series sands from its Manora platform. Both MNA-24H and 23H wells spud in July and reached total measured depths of approx. 2,216 m (7,270 ft) with both wells testing at a reported at a combined rate of 1,978 bopd.

PESGB South East Asia News is sponsored by RISC Advisory, Technical & Economic Advisors to the oil and gas industry. For further information please contact Gavin Ward: Gavin.Ward@riscadvisory.com (Credit: Energy News Bulletin)

Advanced carbonate workshops 2019 18-20th Nov: Mixed carbonate-evaporite systems This workshop presents an overview of the wide variety of carbonate reservoirs that form in different depositional settings and in response to syn- and postdepositional salt movement. Complex diagenesis is also a key control of reservoir quality. Evaporites as source rocks are also discussed. 25-27th Nov: Mexican petroleum systems Mexico offers a large untapped hydrocarbon potential in carbonate and clastic reservoirs. This workshop critically reviews the wide range of Jurassic and Cretaceous carbonate reservoir types and plays and the significance of recent discoveries. 2-4th Dec: Non-marine carbonate systems Discoveries in Brazil have highlighted the complexity of diagenetic and depositional controls of reservoirs in non-marine carbonates. Petroleum systems in the pre-salt and other lacustrine systems are described and other non-marine carbonate systems including karst systems, aeolian and terrestrial conglomeratic carbonates are also reviewed. Location: Cambridge Carbonates Ltd. offices in Solihull £ 2,250-00 per person, per course, discounted rates for clients making multiple bookings For further details contact Peter Gutteridge and website pete@cambridgecarbonates.co.uk or visit www.cambridgecarbonates.com

PESGB October 2019 55

PES DRILLING ACTIVITY UNITED KINGDOM To date in 2019, nine exploration wells and three appraisal wells have completed in the UK. In the West of Shetland, CNOOC spudded its 206/21-1 Howick exploration well on 31 August with the Island Innovator semi-submersible. The well is targeting Lower Cretaceous sandstones within a four-way dip closure in the West Shetland Basin Hurricane Energy is continuing to drill the 205/26b-14 Lincoln Crestal well which spudded on 12 July. The well is an appraisal of its 205/26b-12 Lincoln well drilled in 2016. The well is appraising 1C - 2C - 3C resources of 150 - 604 - 1,537 mmboe, based on an RPS Energy CPR published December 2017. Hurricane announced on 2 September that the well has reached total depth at 1,780m (5,840ft) TVDSS, having drilled a 720m (2,362ft) horizontal section into the fractured basement reservoir. On 9 September, Hurricane confirmed that a DST has produced oil to the surface, resulting in a flare. The well has subsequently been shut-in to enable a planned pressure build-up test. Drilling is continuing at Total’s 206/4a-5 and -5Z Glendronach appraisal well, which spudded on 16 July. The well is seeking to appraise volumes reported by the operator to be in the region of 1 tcf (166.6 mmboe) in the Lower Cretaceous Royal Sovereign Formation. A mechanical sidetrack was kicked off on 28 August as the 206/4a-5Z well. CNOOC is continuing to drill the 208/17a-4 Cragganmore appraisal well, which spudded on 19 July with the Ocean GreatWhite semisubmersible. The original discovery was made in 2012, encountering low saturation gas in Paleocene Vaila Formation sandstones within a 56 PESGB October 2019

North Sea News structure estimated to be c. 50 km2. In the Northern North Sea, with the completion of Equinor’s Bigfoot exploration well 9/22a-4A on 12 February, there is currently no drilling taking place. The next well that is expected to spud is Cairn’s 3/17a-C Chimera exploration well in October 2019. In the Central North Sea, i3 Energy announced on 10 September that its 13/23c-9 Liberator well (Phase I, LPt-02 pilot appraisal) has failed to encounter hydrocarbons. The target Upper Captain Member reservoir is pinched out at the well location and the Lower Captain sandstones were dry, as expected. The well was spudded on 21 August and reached total depth at 5,818ft (1,773m) TVDSS in the Valhall Formation with the Borgland Dolphin semi-submersible rig. The forward plan is to obtain a Vertical Seismic Profile and run a shear-wave sonic log before being plugged and abandoned. In the Southern North Sea, Premier Oil spudded the 42/28d-14 Tolmount East appraisal well on 8 August with the Valaris (previously Ensco) 123 jack-up rig. The well is targeting 300 bcf in the Permian Rotliegend as an extension of the Tolmount Main field, which would be incorporated into the c. 500 bcf Tolmount development. Operations were completed at ONE-Dyas’s 42/4-1Z Darach exploration well on 30 August with the Ensco 121 jack-up rig, having spudded on 16 May. The well was sidetracked on 8 July after 54 days of drilling, approximately one week after the estimated time to top reservoir. On 23 July, ONE-Dyas applied to the OGA to undertake an Extended Well Test (EWT), which may imply that the well has encountered hydrocarbons. The well was targeting Lower Carboniferous sandstones with secondary potential in Zechstein carbonates. Spirit Energy is continuing to drill

the 43/12a-3 Andromeda North exploration well, which spudded on 29 July with the Noble Hans Deul jackup. According to the JV, the well is targeting volumes of 40 bcf in the Carboniferous, which in the event of success will be incorporated into the adjacent Pegasus development.Operations are continuing at Independent Oil & Gas’s 48/24b-6 Harvey appraisal well, which spudded on 6 August with the Maersk Resilient jack-up rig. The operator announced on 11 September that it had reached total depth at 7,537ft (2,297m) MD in Permian Leman sandstones. The top of the Leman sandstone was encountered at 7,086ft (2,160m), which was found to contain a 49ft (15m) gas column. UK ONSHORE The West Newton A-2 appraisal well was spudded on 26 April 2019 targeting the Permian Kirkham Abbey Shoal gas discovery and Cadeby Reef oil prospect. The well encountered a 65m (213ft) hydrocarbon column in the Kirkham Abbey Shoal Formation that in September was defined as a 20m (66ft) gas column and 45m (148ft) oil column. Due to the potential of a significant oil column, the EWT of the Kirkham Abbey Shoal Formation, that started on 24 August, was temporarily suspended on 29 August to revise the test design. Pre-drill, the Permian Abbey Shoal gas discovery had estimated P90-P50-P10 resources of 95 - 189 - 376 bcf and this will be updated based on the well results. Four further wells, Springs Road-1, Preston New Road-1Z, Preston New Road -2 and Horse Hill-1, remain active. Springs Road-1 encountered three shale targets on prognosis with indications of gas at each interval and has undergone a comprehensive logging and core analysis program that has had encouraging results. Future plans and final technical

N E W S F E AT U R E

Well

Operator Class

42/4-1Z

Premier

App

Type Sidetrack

42/4-1

Start Date

End Date

05/07/19

30/08/19

21/05/19

05/07/19

12/07/19

28/08/19

16/07/19

28/08/19

Active

19/07/19

WOS

Licence

Target

Age

Status

P2133

Darach

Carboniferous

P&A

P1368

Lincoln

Basement

Active

P1453

Glendronach

Cretaceous

Active

Cragganmore

Paleocene

Initial

205/26b-14

Hurricane

App

Total

App

Initial Sidetrack

206/4a-5Z 206/4a-5

Initial

Basin SNS WOS WOS

208/17a-4

CNOOC

App

Initial

P1598

43/12a-3

Spirit

Exp

Initial

P2128 AndromedaNorth Carboniferous

Active

29/07/19

SNS

48/24b-6

IOG

App

Initial

P2085

Harvey

Permian

Active

06/08/19

SNS

42/28d-14

Premier

App

Initial

P1330

Tolmount East

Rotliegend

Active

08/08/19

SNS

Active, Dry

21/08/19

CNS

Active

31/08/19

WOS

13/23c-9

i3 Energy

App

Initial

P1987 LiberatorLPt-02

206/21-1

CNOOC

Exp

Initial

P2298

Howick

Lower Cretaceous Lower Cretaceous

Current and recent E&A drilling activity in UK. Source: Westwood Atlas Well

Operator

Class

Type

Licence

Target

Age

Middle Jurassic, Iris/Hades LowerCretaceous Triassic, Middle Sputnik Jurassic

6506/11-11S

OMV

App

Initial

644

7324/6-1

Equinor

Exp

Initial

855

16/5-8 S

Lundin

Exp

Initial

815

Goddo

6608/11-9

Cairn

Exp

Initial

842

6608/6-1

Aker BP

Exp

Initial

6507/2-5 S

Equinor

Exp

6407/3-2 S

Equinor

30/12-2

Status

Start Date

End Date

Basin

Active

31/05/19

Norwegian Sea

P&A Oil

18/06/10 31/07/19

Barents Sea

Basement

P&A Oil

08/07/19 22/08/19

Central N. Sea

Godalen

Upper Jurassic

P&A Dry

13/07/19 05/08/19 Norwegian Sea

762

Vågar

Permian

P&A Dry

19/07/19 11/08/19 Norwegian Sea

Initial

942

Ørn

Middle Jurassic

Active

Exp

Initial

796

Lanterna

Middle Jurassic

P&A Dry

Aker BP

Exp

Initial

986

Nipa

Middle Jurassic

P&A

25/4-14 S

Aker BP

App

Initial

036C

Alvheim

Paleocene

25/7-7

ConocoPhillips

Exp

Initial

782 S

Busta

2/1-17 S

Aker BP

Exp

Initial

019C

6507/5-9 S

PGNiG

Exp

Initial

838

23/07/19

Norwegian Sea

06/08/19 05/09/19 Norwegian Sea 14/08/19 27/08/19

North N. Sea

Active

28/08/19

North N. Sea

Upper Jurassic

Active

29/08/19

North N. Sea

Kark

Upper Jurassic

Active

30/08/19

Central N. Sea

Shrek

Middle Jurassic

Active

30/08/19

Norwegian Sea

Current and recent E&A drilling activity in Norway. Source: Westwood Atlas Country

Deal Type

Buyer

Seller

Key Asset(s) Involved

Farm-in

DNO

Cairn

Chimera prospect

Deal activity (Source: Westwood Atlas) PESGB October 2019 57

PES North Sea News (cont.) results are due to be announced in Q3. The long-term production testing at Horse Hill-1 was switched from the Portland Sandstone back to the Kimmeridge Limestones in July. The Horse Hill-2 well is expected to spud this month. Cuadrilla’s Preston New Road-1Z well had previously been carrying out fraccing operations but there has been no testing activity since December 2018. Fraccing began at Preston New Road-2 well on 15 August, however micro-seismic events have caused the OGA to declare an indefinite suspension of fraccing of the well since 26 August. NORWAY To date in 2019, 33 exploration wells and three appraisal wells have completed in Norway. During August four exploration wells completed, and five exploration wells and one appraisal well were spudded. In the North Sea, Aker BP spudded appraisal well 25/4-14 S on 28 August with the Deepsea Stavanger rig. The well is aimed at de-risking infill well opportunities in Alvheim field for a potential 2020 infill well programme. The well has an estimated duration of 22 days. ConocoPhillips spudded the Busta exploration well 25/7-7 on 29 August with the Leiv Eiriksson semi-submersible. The well is targeting predrill resources in the range 54 - 199 mmboe (mid-point 126.5 mmboe) in Upper Jurassic Intra-Draupne Braeequivalent sandstones and has an estimated duration of 47 days in the dry hole case. On 30 August Aker BP spudded its Kark exploration well 2/1-17 S with the Maersk Interceptor. The well is targeting Upper Jurassic Ula Formation prospectivity south of the Gyda field with secondary targets in the Middle Jurassic and Triassic. Pre-drill resources are reported by the operator to be in the range 15 48 mmboe (mid-point 31.5 mmboe). The Aker BP-operated 30/12-2 58 PESGB October 2019

Nipa exploration well spudded on the 14 August with the Deepsea Stavanger rig. The well was targeting pre-drill resources of 35 - 115 mmboe in the Middle Jurassic Tarbert and Ness Formations of the Brent Group. The well tested a new hydrocarbon migration pathway onto the Bjørgvin Arch from the Viking Graben and was expected to complete in 28 days if successful. However, the well failed to find hydrocarbons and was abandoned as a dry hole on 27 August. Lundin spudded its Goddo exploration well 16/5-8 S on 8 July with the Leiv Eiriksson rig targeting pre-drill resources of 112 mmboe in fractured basement on the Utsira High, close to the operator’s Edvard Grieg field. The well encountered a 20m (66ft) oil column in fractured Basement with preliminary resources of 1 - 10 mmboe according to Lundin. It has been reported that there is upside in the area and further refinement of the discovery is expected after an EWT of the Rolvsnes discovery. The well has been plugged and abandoned. In the Norwegian Sea, PGNiG spudded its first operated well in Norway on 30 August, targeting predrill resources in the range of 10 - 22 mmboe in the Middle Jurassic, Garn Formation, Shrek prospect. The well has secondary objectives in the Upper, Middle and Lower Jurassic. Lime Petroleum farmed-in to the licence in June 2019. Equinor spudded the 6407/3-2 S Lanterna exploration well on 6 August with the West Hercules rig. The well was targeting oil in the Middle - Lower Jurassic Fangst and Båt Groups on the western Trøndelag Platform with secondary prospectivity in Upper Triassic fluvial channel sandstones, however it was announced on 10 September as having failed to find hydrocarbons. On 19 July, Aker BP spudded exploration well 6608/6-1 with the Deepsea Stavanger rig targeting

pre-drill gas resources equivalent to 63 - 130 mmboe in Permian carbonates within the frontier Vågar prospect. The well encountered 285m (935ft) of Permian Zechstein Group carbonates that are partially tight and partially poor reservoir quality, with 4m (13ft) of moderate reservoir quality carbonates. The reservoir was water wet and the well was abandoned on 11 August. Cairn spudded its Upper Jurassic Godalen exploration well 6608/11-9 on 13 July with the Transocean Arctic rig, targeting prospective resources of 90 mmboe in Upper Jurassic Rogn Formation sandstones. The well failed to encounter the Rogn Formation, instead encountering 40m (118ft) of sandstone in the Upper Jurassic Melke Formation, however the reservoir was water wet. The well was abandoned on 5 August. Equinor spudded its Ørn prospect 6507/2-5 S exploration well on 23 July targeting the Middle - Lower Jurassic with pre-drill resources of 8 - 40 mmboe, which in the success case will be tied back to the Skarv field. There is secondary potential in the Cretaceous. On 31 May, OMV spudded appraisal well 6506/11-11 S with the Deepsea Bergen targeting the Middle Jurassic and Lower Cretaceous Iris and Hades discovery made in 2018 with well 6506/11-10. Mid case resources are estimated at 640 bcf gas and 26 mmbbl liquids (133 mmboe). The initial well is expected to have duration of between 75 and 120 days, depending on the result, and is ongoing at the time of writing. There is an option for a sidetrack well which will extend the total duration to around 178 days. In the Barents Sea, Equinor’s Sputnik exploration well 7324/6-1 spudded on 18 June with the West Hercules rig. The well targeted the Upper Triassic Snadd Formation sands with a secondary objective in

N E W S F E AT U R E

the Middle Jurassic Stø Formation. The well encountered a 15m (49ft) oil column in poor reservoir quality sandstones of the Snadd Formation. Further poor reservoir quality sandstones within the Snadd Formation and good reservoir quality sandstones of the Stø Formation were water wet. Preliminary resources were estimated at 20 - 65 mmboe by Equinor.

UK ONSHORE On 11 September UKOG announced it had completed the acquisition of Magellan Petroleum (UK) Investment Holdings Limited, a subsidiary of Tellurian Investments, that holds a 35% interest in the Horse Hill oil field and the PEDL 137 and PEDL 246 licences for £12 million in cash and shares. The deal increased UKOG’s net interest in the Horse Hill discovery from 50.635% to 85.635%.

DEAL ACTIVITY UNITED KINGDOM DNO has farmed-in to acquire a 15% interest from operator Cairn in Northern North Sea licence P2312, including blocks 3/16a and 3/17a, and will participate in the forthcoming Chimera exploration well which is expected to spud in 2019. The deal follows the farm-in by Suncor earlier in year, with both deals having resulted in Cairn’s interest reducing from 100% to its current 45%.

NORWAY No new deals have been announced since the last report, however two deals have been completed. Mime Petroleum’s acquisition of a 10% interest from Vår Energi in the North Sea Balder and Ringhorne fields was announced on 1 August as having now completed. The deal provides Mime with its first producing assets in Norway, with net 2019 production estimated at 3,600 boepd. This is expected to increase to c.

7,000 boepd by 2025 as a result of a planned redevelopment of both fields. At the end of August, it was announced that the two transactions between Equinor and Lundin have now completed. Equinor has increased its equity in Johan Sverdrup by 2.6% for a consideration of US$910 million plus a contingent payment of US$52 million. It has reduced its shareholding in Lundin by 16%, which equates to c. 54.5 million shares at a price of SEK266.4 per share, for which it will receive US$1.557 billion based on exchange rates at the time of the deal. It will also retain a 4.9% equity stake in Lundin.

PESGB North Sea News is sponsored by Westwood Global Energy Group For further information please contact David Moseley: dmoseley@westwoodenergy.com

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PESGB October 2019 59

PES Title:

North America to drive global LNG supply growth

Publication: PESGB Newsletter Authors:

Olga Kerimova and Veronika Akulinitseva, VP Analysis

Date:

2 September 2019

Olga Kerimova & Veronika Akulinitseva, Senior Analysts, Rystad Energy

North America to drive global LNG supply growth

Following flattish development during the downturn, global LNG production is expected to expand in the mid- to long-term, reaching 455 million tpa by 2025. North America is anticipated to display the highest growth in terms of production and investments going forward with multiple projects coming online by 2025. This article assesses the outlook for global LNG, illustrated by three key drivers: supply, breakeven prices for new projects and capital investments.

Following flattish development during the downturn, global LNG production is expected to expand in the mid- to longterm, reaching 455 million tpa by 2025. North America is anticipated to display the highest growth in terms of production and investments going forward with multiple projects coming online by 2025. This article assesses the outlook for global LNG, illustrated by three key drivers: supply, breakeven prices for new projects and capital investments. Figure 1 shows global LNG production split by region, from 2010 to 2025. In 2018, there was 321 million tpa of LNG produced, an increase of 12% relative to 2017. In order to keep up with increasing LNG demand, global production is expected to continue to grow going forward, hitting 455 million tpa by 2025. Around 65% of the future LNG volumes will come from sanctioned projects, which includes increasing volumes from the US and Australia. As of today, the Middle East is the largest supplier of LNG with Qatar being the biggest contributor to nearly 100 million tpa supplied by the region each year. North America, however, is anticipated to replace the Middle East as the largest LNG Olga Kerimova, Senior Analyst olga.kerimova@rystadenergy.com

60 PESGB October 2019

450 Other 400 North Africa 350 South America 300 Russia

250

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200

North America

150

Australia

100

South East Asia

50 0 2010

Middle East 2012

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Figure 1: Global LNG supply by region – Million tonnes LNG. (Source: UCube from Rystad Energy, Figure 1: Global LNG supply by region – Million tonnes LNG. (Source: UCube September 2019)

from Rystad Energy, September 2019)

Figure 1 shows global LNG production split by region, from 2010 to 2025. In 2018, there was 321 million tpa of LNG produced, an increase of 12% relative to 2017. In order to keep up with increasing producer by 2025. With nearly inexsupplier with top companies aspiring LNG demand, global production is expected to continue to grow going forward, hitting 455 million istent LNG supplies before 2017, the to take a share in global LNG market. tpa by 2025. Around 65% of the future LNG volumes will come from sanctioned projects, which United States is actively ramping up Novatek’s operated Yamal LNG proincludes increasing volumes from the US and Australia. As of today, Middle East is the largest output on its key LNG projects, injecttoisnearly reaching full capacity supplier of LNG with Qatar being the biggest contributor 100 million tpa suppliedinby2019the cluding Pass, Freeport, 2020 and several newasprojects, region eachSabine year. North America, however, and is anticipated to replace Middle East the largest such LNG CorpusbyChristi. Over next LNG three Arctic LNG 2,States are isanticipated to producer 2025. With nearlythe inexistent suppliesas before 2017, United actively ramping years, USkeywill ~35 including million tpa begin service in theChristi. next Over five the years. up outputthe on its LNGadd projects, Sabine Pass, Freeport, and Corpus next of LNG supply, as add projects starttpa operTotalasRussian output is thus three years, the US will ~35 million of LNG supply, projects start operations, andexpectis set to

ations, and is set to flood the market volumes. The majority of US supply is contracted by portfolio players or traders, with the purpose of reselling the volumes. In addition to the US ramp up, Australia’s Ichthys and Prelude projects are expected to reach full capacity next year bringing total Australian supply to about 80 million tpa. Russia is also emerging as an important LNG

with here] flexible [Type

Veronika Akulinitseva, Senior Analyst veronika@rystadenergy.com

ed to reach about 30 million tpa by 2025, with Russia entering the top 5 global LNG producers. Figure 2 shows breakeven prices for the top upcoming LNG projects expected to be sanctioned in the next three years. On August 19th this year, Venture Global took the final investment decision on the $5.8 billion Calcasieu Pass project in Louisiana, United States. Area 1 LNG in Mozambique

N E W S F E AT U R E

was sanctioned by Anadarko in June 2019, and has an estimated breakeven price of 5.5 USD/MMBtu. The first train of Woodfibre LNG in Canada, as well as Mozambique’s Area 4 (Rovuma) and Russia’s Arctic LNG 2 are also expected to reach FID this year. These projects are expected to break even at 6 – 6.4 USD/ MMBtu. In the next two years we expect to see the sanctioning of Driftwood LNG and Freeport LNG Train 4 in the United States, as well as Papua LNG, Pluto LNG Train 2 and QatarGas LNG Trains 8-11. QatarGas LNG has the lowest breakeven price among the top upcoming projects, at 4.5 USD/MMBtu. On the other hand, Papua LNG, with an estimated breakeven of over 8 USD/MMBtu, is one of the more expensive projects, which combined with the political uncertainty surrounding the project could mean sanctioning delays. Along with Mozambique, the United States dominates the new LNG project list, and is positioning itself for a significant LNG export growth as the Federal Energy Regulatory Commission (FERC) has this year reached a new record in approvals of US LNG. Figure 3 depicts total capital investments into LNG developments by life cycle of the projects included. Global LNG capital expenditures were increasing sharply from 2010 and peaked in 2014 at over $40 billion. Following the oil price collapse, investments were falling by 14% CAGR in 2015-2018, particularly driven by reductions in Australia. As Gorgon, Australia Pacific and other major projects neared completion, the country significantly reduced influx of capex into new developments. Thus spending was decreased by more than 80% since 2014. At the same time, North American projects saw the largest injection of capital during the downturn. This region is also forecasted to exhibit the largest growth in spending in the future, directed to new unsanctioned projects. Among these, Driftwood LNG is the largest development, which will see an average of around $2.5 billion invested yearly in 2021-2025. Currently, active investment is going into sanctioned, but not yet producing projects, including Freeport LNG, estimated to start-up later this year, LNG Canada, and Golden Pass. Similarly, LNG investments in Russia are set to pick-up again after the decrease of 2016-2019 that followed after the completion of Yamal LNG. Arctic LNG 2 project, the second Novatek operated project to be developed, will be the first to come online by 2025. The construction phase is planned to start already this year, leading to a substantial increase in spending in the following years. Globally, LNG capital investments are now forecasted to reach 2014 levels again by 2025.

flood the market with flexible volumes. The majority of US supply is contracted by portfolio players or traders, with the purpose of reselling the volumes. In addition to the US ramp up, Australia’s Ichthys and Prelude projects are expected to reach full capacity next year bringing total Australian supply to about 80 million tpa. Russia is also emerging as an important LNG supplier with top companies aspiring to take a share in global LNG market. Novatek’s operated Yamal LNG project is reaching full capacity in 2019-2020 and several new projects, such as Arctic LNG 2, are anticipated to begin service in the next five years. Total Russian output is thus expected to reach about 30 million tpa by 2025, with Russia entering the top 5 global LNG producers. QatarGas LNG T8-11

4.5

Mozambique LNG (Area 1)

Qatar United States

5.5

Rovuma LNG (Area 4)

5.9

Arctic LNG 2

Calcasieu Pass LNG

Freeport LNG T4

6.3

Pluto LNG T2

6.4

Woodfibre LNG

6.4

Driftwood LNG

Russia Mozambique Papua New Guinea Australia Canada

7.6

Papua LNG

8.4 0

Figure 2: price Breakeven price selected new LNG projects Figure 2: Breakeven for selected new LNG for projects – USD/MMBtu (Source: UCube from Rystad – USD/MMBtu (Source: from Rystad Energy,opex and Energy, September 2019). Breakeven priceUCube includes feed gas, LNG capex, liquefaction transportation cost to East Asia. Breakeven price includes feed gas, LNG September 2019). capex, liquefaction opex and transportation cost to East

Figure 2 shows breakeven prices for the top upcoming LNG projects expected to be sanctioned in the Asia. next three years. On August 19th this year, Venture Global took the final investment decision on the $5.8 billion Calcasieu Pass project in Louisiana, United States. Area 1 LNG in Mozambique was exportby projects. sanctioned Anadarko in June 2019, and has an estimated breakeven price of 5.5 USD/MMBtu. The first train of Woodfibre LNG in Canada, as well as Mozambique’s Area 4 (Rovuma) and Russia’s Arctic LNG 2 are 45also expected to reach FID this year. These projects are expected to break even at 6 – 6.4 USD/MMBtu. In the next two years we expect to see the sanctioning of Driftwood LNG and Freeport 404 in the United States, as well as Papua LNG, Pluto LNG Train 2 and QatarGas LNG Trains 8LNG Train 11. QatarGas LNG has the lowest breakeven price among the top upcoming projects, at 4.5 35 USD/MMBtu. On the other hand, Papua LNG, with an estimated breakeven of over 8 USD/MMBtu, is one of the 30 more expensive projects, which combined with the political uncertainty surrounding the Discovery project could mean sanctioning delays. Along with Mozambique, the United States dominates the new LNG25project list, and is positioning itself for a significant LNG export growth as the Federal Under development Energy Regulatory Commission (FERC) has this year reached a new record in approvals of US LNG 20 15

Producing

[Type here] 10 5 0 2010

2012

2014

2016

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2024

Figure 3: Total capital investments into LNG by life cycle – Billion USD (Source: UCube from Rystad Figure 3: Total capital investments into LNG by life cycle – Energy, September 2019) Billion USD (Source: UCube from Rystad Energy, September 2019) Figure 3 depicts total capital investments into LNG developments by life cycle of the projects included. Global LNG capital expenditures were increasing sharply from 2010 and peaked in 2014 at over $40 billion. Following the oil price collapse, investments were falling by 14% CAGR in 2015-2018, particularly driven by reductions in Australia. As Gorgon, Australia Pacific and other major projects neared completion, the country significantly reduced influx of capex into new developments. Thus CONCLUSION spending was decreased by more than 80% since 2014. At the same time, North American projects Global LNG production and investments are expected to saw the largest injection of capital during the downturn. This region is also forecasted to exhibit the grow in the medium longer term, by recently sanc-these, largest growth in spending in theto future, directed to new led unsanctioned projects. Among Driftwood LNG largest development, whichin willNorth see an average of around $2.5 billion invested tioned andis the upcoming projects America. Multiple yearly in 2021-2025. Currently, active investment is going into sanctioned, but not yet producing LNG projects in the United States, as well as Canada, projects, including Freeport LNG, estimated to start-up later this year, LNG Canada, and Golden Pass. are planned to be commissioned by including Similarly, LNG investments in Russia are set to pick-up again after2025, the decrease of 2016-2019 that followed after the completion Yamal LNG. Arctic LNG of 2 project, the second Novatek operated Driftwood LNG andofthe fourth train Freeport LNG. The project to be developed, will be the first to come online by 2025. The construction phase is planned sanctioning of QatarGas LNG Trains 8-11 and Russia’s to start already this year, leading to a substantial increase in spending in the following years. Arctic LNG is further expected boost global Globally, LNG capital2investments are now forecasted toto reach 2014 levels again byLNG 2025.

supply post 2025. Conclusion Global LNG production and investments are expected to grow in the medium to longer term, led by recently sanctioned and upcoming projects in North America. Multiple LNG projects in the United States, as well as Canada, are planned to be commissioned by 2025, including Driftwood LNG and the [Type here]

PESGB October 2019 61

Parkmead Group

Company Profile

The Parkmead Group is a UK and Netherlands focused independent energy group listed on the Alternative Investment Market of the London Stock Exchange (AIM: PMG). The Group currently produces gas from a portfolio of four fields across the Netherlands and holds oil and gas interests spanning 26 exploration and production blocks. Parkmead has significant development opportunities across the UK and Netherlands, including the Greater Perth Area development located in the UK Central North Sea. The Group also holds interests in a portfolio of exploration prospects alongside leading international partners. Parkmead is continually expanding its portfolio of high quality assets covering the three main areas of E&P operations; exploration, development and production. Production As at December 2018, Parkmead produces approximately 650 barrels of oil equivalent per day from a portfolio of four gas fields in the Netherlands. Parkmead holds a 7.5% to 15% working interest in four producing onshore gas fields in the Netherlands; Geesbrug, Brakel, Grolloo and Diever West. Development Parkmead holds a selection of assets in the development stage of the asset life cycle. The company operates the Greater Perth Area ("GPA") oil hub project in the UK Moray Firth, and holds stakes in a number of nearby oil fields which could potentially form part of a large joint development, such as Lowlander, Polecat and Marten. In addition, Parkmead has a stake in the Platypus gas development in the Southern North Sea and a number of oil and gas developments in the Netherlands. Exploration Parkmead has interests in numerous e x p l o ra t i o n b l o c k s i n t h e U K a n d Netherlands, ranging from high impact exploration in the UK West of Shetlands to near-term exploration onshore Netherlands. The group was awarded interests in 9 blocks in the UKCS 30th Licensing Round. This builds upon prior success in the UKCS 27th and 28th Licensing Rounds, where interests in 30 and 12 blocks were awarded respectively.

NETHERLANDS The Parkmead portfolio includes producing gas fields with a very low operating cost. This profitable gas production from the Netherlands provides important cash flow to the Group. Average gross production at Diever West during the first half of 2019 was 48.1 MMscfd, approximately 8,293 boepd. The Group substantially increased production from the Diever West gas field in 2018. After perforating the Akkrum formation section of the reservoir, a change in production tubing was successfully completed on the field. This intervention has led to the production achieving its full potential from the two perforated intervals.

62 PESGB October 2019

The Diever West field has performed above expectations since its first production. Dynamic reservoir modelling suggests that the field holds approximately 108 billion cubic feet of gross gas-in-place, this is more than double the earlier, post-drill static volume estimate of 41 billion cubic feet. A large number of further exploration opportunities exist within the Drenthe VI concession, which contains the Diever West field. The Boergrup prospect, located to the w e s t o f D i e v e r, i s a s t a c k e d Rotliegendes/Vlieland sandstone structure situated between three productive fields; De Hoeve, Vinkega and Diever West. A further significant prospect on the Drenthe VI licence is Leemdijk. Leemdijk consists of three fault bounded dip closures which are potentially in communication, forming one larger structure. Detailed work has begun on the Ottoland oil and gas discovery, located on the same Andel Va block as the Brakel gas field. The Ottoland discovery well encountered 75ft of net oil pay in two Triassic sandstone formations. Seismic interpretation and depth migration studies, followed by structural and static modelling, will refine the volumetrics ahead of a development plan, potentially including a new horizontal well. In addition, seismic reprocessing has been completed on the Andel Vb licence ahead of updating the prospectivity estimates for this area. At Parkmead’s producing Geesbrug gas field, the potential for a new low-cost infill well is being studied in order to maximise production. In addition, compressor optimisation work at the Grolloo field is expected to be carried out in 2019.

UK In May 2018, Parkmead was provisionally awarded nine new UK oil and gas blocks and part blocks spanning five new licences in the UK 30th Licensing Round. These new licences were formally awarded in the second half of 2018 and Parkmead’s experienced team have begun various work programmes across the blocks. These newly awarded licences are all operated by Parkmead and are located in the Central North Sea, Southern North Sea and West of Shetland areas. Two of the new awards cover the highly prospective Skerryvore area and contain seven new prospects, three of which are stacked. The Skerryvore Mey prospect overlies two stacked Chalk prospects (Skerryvore Ekofisk and Skerryvore Tor) which are associated with Skerryvore, a Zechstein salt diapir. The Chalk in these prospects is thought to have been reworked, which significantly improves permeability over conventional Chalk reservoirs. These three stacked prospects have the potential to contain 157 million barrels of recoverable oil equivalent on a P50 basis. An additional Paleocene Mey prospect (Skerryvore West) and one Chalk prospect (Skerryvore North) are also identified on the blocks. The proposed work programme includes rock physics studies, reprocessing 3 D s e i s m i c a n d a co nt i n ge nt we l l .

Parkmead’s co-venturers on the licence are Serica Energy, Zennor Petroleum and CalEnergy Gas. Parkmead’s equity stake is 30%. These new awards also include acreage containing the Lowlander oil field, in close proximity to Parkmead’s GPA project. Lowlander lies 17km north west of the Parkmead operated Perth field which is at the centre of the Company’s GPA oil hub project. Lowlander is an Upper Jurassic Piper sandstone discovery, appraised by five wells and contains 2C oil resources of 20.5 million barrels of recoverable oil on a P50 basis. The Lowlander field is strategically important to Parkmead because it could be developed in conjunction with the GPA project. The block also contains Midlander, an Upper Jurassic turbidite sandstone discovery to the north east of Lowlander that could add to Parkmead’s resource base in the area. The work programme consists of obtaining 3D seismic and a drill or drop well. The addition of the Lowlander field increases Parkmead’s 2C resources by 37% to 100.9 MMBoe. Parkmead has been awarded one new licence adjacent to an existing block that is already operated by the Group in the West of Shetland area. Block 205/12 (Parkmead 100%) is situated in the Faroe-Shetland Basin immediately to the west of the Parkmead operated block 205/13, which contains the Sanda prospect. One large prospect, Davaar, has been identified in Block 205/12 and is a combination structural and stratigraphic trap in the Vaila Formation. The Palaeocene Vaila Formation is the primary play fairway on this acreage and forms the reservoir in the adjacent Foinaven, Schiehallion and Loyal oil fields and the Laggan and Tormore gas fields. Parkmead will undertake reprocessing of the existing legacy seismic with a new 3D seismic shoot, contingent on the results, and a drill or drop well. Davaar has the potential to contain 204 million barrels of recoverable oil on a P50 basis. Parkmead has been awarded a new licence in the Southern Gas Basin. This is an area where the Company has a deep technical knowledge of exploration plays and is building a portfolio of targets. Parkmead has already had significant success in the Southern Gas Basin with the gas discovery at Platypus. The field was subsequently appraised with a horizontal well and flow tested at a rate of 27 MMscfd (approximately 4,600 boepd on an equivalent basis). Blocks 47/10d & 48/6d (Parkmead 75%) contain the Blackadder prospect and Teviot gas discovery. The Permian Rotliegendes Sandstone is the primary play fairway on the acreage and is proven productive by the numerous discoveries in the area including West Sole, Hyde and Amethyst. The work programme contains a drill or drop well. Parkmead’s co-venturer on this licence is Cluff Natural Resources. Considerable progress has been made at Parkmead’s Platypus gas field development. The joint venture partnership is currently working towards optimising the export route

Parkmead Group

West of Shetland

Company Profile 1. West of Shetland Parkmead holds two adjacent licences in the highly prospective West of Shetland area. These blocks were awarded to the Group through the UKCS 28th and 30th Licensing Rounds and are both operated by Parkmead.

2. UK Moray Firth Parkmead holds a significant position in the prolific UK Moray Firth, an area which contains major North Sea oil fields such as Piper, Claymore and Tartan. This position has been established both through licensing round success and strategic acquisitions.

Moray Firth Aberdeen

Central North Sea

3. UK Central North Sea Parkmead was awarded two significant new licences in the Central North Sea as part of the UK 30th Licensing Round.

Southern North Sea 5 Netherlands onshore

London

for Platypus ahead of an offtake agreement. Various export options are available to the partnership, given the extensive availability of infrastructure in the UK Southern Gas Basin. First gas at Platypus is targeted for 2021 at rates in excess of 50 MMscfd per day, not including the additional upside from the Possum prospect which is planned to be drilled as part of the development. Parkmead has entered into commercial discussions with the Scott field partnership, led by China National Offshore O i l Corporation (CNOOC) International, in order to explore terms for a tie-back of the GPA oil hub project to the Scott facilities. The Scott facilities lie just some 10km southeast of the GPA project and a tie-back could yield a number of mutually beneficial advantages for both the Scott partnership and Parkmead. A tie-back to Scott is one path to potentially unlock the substantial value of the GPA project. Parkmead is also holding discussions with a number of leading, internationally-renowned service companies in relation to the GPA project. Renewable Energy In August 2019, Parkmead acquired the entire issued share capital of Pitreadie Farm Limited, a company owning extensive farmland and sites in Scotland with

significant renewable energy potential. Potential has been identified for the installation of numerous wind turbines, a solar farm and a biomass production facility on the acquired land, totalling some 2,320 acres. The renewables sector is a natural expansion of Parkmead’s energy operations and is fully in line with the Group’s strategy to increase the balance of Parkmead’s portfolio. Parkmead recognises the transition that is taking place in the energy market, supported by legislation, from fuels with a higher carbon content to lower carbon alternatives such as natural gas and renewables. Natural gas and renewables play key roles in the generation of electricity. In light of these important energy market factors, Parkmead transitioned to a gas-only producer in January 2016 and the Group has increased its gas production almost tenfold since 2014. Parkmead remains of the strong belief that oil and gas will have a very important role to play in the energy mix in future years. This is evidenced by a range of forecasts showing robust and increased demand for oil and gas going forward.

Thank you to KeyFacts Energy for this oil company profile. Contact Chris Pettit if you have a company profile suggestion. e. chris@keyfactsenergy.com t. 07590 442868

4. UK Southern North Sea In the UK Southern North Sea, Parkmead has built an extensive portfolio of both gas fields and exploration prospects. The Group holds a 15% working interest in the Platypus gas field, which was discovered in 2010. In August 2012, Platypus was successfully appraised and recorded a test flow rate of 27mmscf per day on a 96/64” choke (approximately 4,600 barrels of oil per day on an equivalent basis). 5. Netherlands onshore Parkmead acquired its Netherlands portfolio from Dyas B.V. in March 2012 (completed in August 2012). The acquisition marked a significant milestone for Parkmead by adding four producing gas fields, three oil & gas developments and a number of exploration prospects. The Group believes that now is the optimum time to broaden Parkmead’s low-cost, lowcarbon operations. The renewables sector is a n at u ra l ex pa n s i o n o f Pa r k m ead ’s operations and is fully in line with the Group’s strategy to increase the balance of Parkmead’s portfolio.

Board Thomas Cross Executive Chairman Ryan Stroulger Finance Director Dr Colin Percival Technical Director Philip Dayer Non-Executive Director Ian Rawlinson Non-Executive Director

Contact Group Headquarters The Parkmead Group plc. 4 Queen's Terrace Aberdeen AB10 1XL Tel: 01224 622200 Email: enquiries@parkmeadgroup.com

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PES Consultant Directory AKM Geoconsulting Ltd Dr Adam K Moss – Core Analysis Petrophysicist Core provides a unique opportunity to “see and touch” a reservoir: AKM Geoconsulting can help you make the most of this prospect. Adam Moss is a core analysis expert with over 25 years’ petrophysical experience; he works with assets and multi-functional teams to define best-practice workflows and ensure high quality core analysis data. He can also help with: design and management of SCAL test programmes, core to log integration, building saturation height function models and integration of core data into reservoir models. Adam provides bespoke training on a wide range of petrophysical topics to an international portfolio of clients. adam@akmgeo.co.uk +44(0)785 8089247 www.akmgeo.co.uk Adinvenio Multimedia Ltd Dr Greg Samways – Petroleum Geologist Petroleum geologist with 20+ years’ experience of geological description and training in all major depositional systems and G&G disciplines, from exploration to production-scale. Specialist in sequence stratigraphy, log analysis, sedimentology, petrography, inorganic geochemistry, diagenetic modelling, reservoir quality analysis and prediction, and reservoir modelling. Experienced project manager skilled at defining workflows, scheduling and delivering focused integrated multidisciplinary play fairway to reservoir-scale studies. +33 (0)5 55 785420 gregsamways@adinvenio.com www.adinvenio.com www.linkedin.com/in/gregsamways Blackbourn Geoconsulting Graham Blackbourn – Sedimentologist & Petrographer Over 35 years’ experience in reservoir evaluation from a microscopic to a basin-wide scale. Specialises in reservoir facies modelling, basin analysis and diagenetic interpretation in hydrocarbon exploration and development. Worldwide experience, especially UKCS, Russia, Central Asia (the “-stans”) and the Far East. Formerly with BNOC/Britoil (Head of Sedimentology) and BP, then 28 years consulting. graham@blackbourn.co.uk 01506 828110 www.blackbourn.co.uk

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Bodecott Consulting Dave Bodecott has been an independent consultant from 1981, also manager and director in world-wide exploration geology and geophysics, specialising in seismic interpretation. From 2004-2013 he was acting or actual Exploration Director of Rockhopper Exploration plc, leading to the discovery of the large Sea Lion Oilfield and satellites, all of which were successfully farmed out. Rockhopper won several City “Explorer of the Year” type awards after the 2010-2012 discovery and appraisal. He has worked for major companies and as consultant for forty years and as NED for other listed companies. www.bodecott.com Chris Clayton – Geochemist Over 30 years experience in all aspects of geochemistry and 1D/3D petroleum system modelling worldwide, including North Sea, Gulf of Mexico, SE Asia, Middle East, North, East, South and West Africa. Special expertise in natural gas problems including biogenic gas exploration and inorganic gas prediction. geochem@c-clayton.com 01584 881318 Geospatial Research Ltd – Integrated Geoscience from Fieldwork, Satellite & Map Data Technology-savvy consultancy with very wide experience spanning most of the world’s petroleum provinces at a variety of scales: from global geodynamics to prospectscale mapping to subseismic fracture networks. Detailed outcrop capture using lidar & UAVs. Many months fieldwork each year. Field training and bespoke field trips. Richard Jones richard@geospatial-research.co.uk www.geospatial-research.co.uk Global Exploration Services Ltd Managing Director: Ray Bate – geologist/biostratigrapher, specialising in Pre-Salt basins of West and Northwest Africa & Brazil, also Pannonian Basin & Middle East; Directors: Andy Carr – Geochemist, basin and petroleum system modeller; Enzo Zappaterra – petroleum geologist; Tony Henshaw management consultant, seismic. Our team, including associates, has over 35 years of work experience, worldwide, working for international oil companies and consultancies. Non- exclusive reports are available for East Africa, West Africa, Libya & the Philippines. Integrated projects undertaken covering all aspects of exploration and production evaluation. 01444-459223 info@globalexplor.com www.globalexplor.com

C O N S U LT A N T S E R V I C E S

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Lomond Associates Sedimentological Consultants Applied reservoir sedimentologists and petrographers with 30+ years of problem solving experience in a wide range of clastic environments, UK and International. Practical reservoir description focused on reservoir quality. Single well, field and regional facies and diagenesis studies are integrated with other disciplines (biostratigraphy, petrophysics, FMI data, chemostratigraphy) to generate robust reservoir models. 01505 843002 mail@lomond-associates.com www.lomond-associates.com Needham Geoscience Limited Dr Tim Needham – Structural geologist Consultant structural geologist with 20+ years of experience worldwide, including NW Europe, Africa, Middle East and the Americas. Work at all scales, ranging from core description to regional tectonics with extensive experience in fault and fault seal analysis, fractured reservoir studies, structural restoration and QC of interpretations for exploration and production. 01943 277030 07884 404373 tim@needhamgeoscience.co.uk www.needhamgeoscience.co.uk OPC (Oilfield Production Consultants Ltd) Integrated Geosciences and Subsurface Engineering Oilfield Production Consultants (OPC) is a consultancy providing fully integrated geosciences, subsurface engineering and reservoir management expertise. We perform a wide range of subsurface geophysical, petrophysical and geological studies as well as seismic interpretation projects. OPC has supported clients in license rounds and our team can quickly evaluate available blocks, map prospects and leads, assess the risk and uncertainty associated with each element of the petroleum system, and provide work programme support moving forward. Regional geological and integrated basin studies can be performed in locations around the world, from frontier to mature basins. OPC can offer farm out services to clients, including evaluating data, constructing and hosting data rooms. Piers Johnson, Managing Director Julie Buckingham, Principal Geoscientist +44 (0)7428 1111 london@opc.co.uk https://opc.co.uk

PDI Thistle Ltd Paul Duley Interpretation Geophysicist Seismic interpreter with over 25 years of UK, Europe, Middle East and Africa experience. Prospect generator. Kingdom software inhouse. Experienced Landmark and Petrel user. PDI.Duley@btinternet.com Petroleum Geology Consulting Limited Dr Stephen J James - Consultant Geologist Specialising in reservoir, development, and production geology, with experience of clastic, carbonate, unconventional, and fractured oil and gas reservoirs principally in NW Europe, Russia, West and East Africa, the Middle and Far East. Services include bespoke technical projects, in-house consultancy, technical reviews, training, and third-party project management. We aim to add value by complementing the experience of our client’s technical teams. How can we help? For more information and discussion of your project needs please contact us. T: +44 (0) 7493 235970 E: stephen.james@petgeoconsult.co.uk W: www.petgeoconsult.co.uk Philip Fish - Seismic Interpretation Consultant 35 years experience as a seismic interpreter - from the majors to the minors. All key areas of exploration covered from basin analysis, regional studies, through to prospect generation, drilling and post well review. Extensive expertise in deep-water hydrocarbon systems, specialising in the integration of seismic and well data to produce robust prospects. AVO practitioner in both Cretaceous and Tertiary deep-water clastics. Extensive Atlantic Margin experience from Falklands to Foz do Amazonas and from Namibia to Norway. Proven track record along the margin of successful regional studies, licence round evaluations and applications to farm-ins and farm outs. Discoverer of hydrocarbons along the South Atlantic margin. Involved as founding partner in start-up company, with a successful IPO ultimately leading to drilling and hydrocarbon discovery. Multi-platform workstation experience. 07952 942048 philipfish@waitrose.com

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C O N S U LT A N T S E R V I C E S

PES

Phil Mollicone Experienced oil industry geophysicist Extensive background of seismic interpretation & mapping; collaborative team working; depth conversion & sensitivity analysis; QI & AVO; and recently seismic acquisition & processing, all of it across a wide range of geologic and geographic provinces. +44 (0) 1777 572 6408 Email: PhilMollicone@aol.com www.linkedin.com/in/pmoll-seismic Pore Scale Solutions Ltd Jon Bouch & Emma Whear Petrographical consultants specialising in reservoir quality evaluation and prediction by the integration of petrography, diagenetic modelling, geochemistry and pore system analysis, with sedimentological and petrophysical data. 01209 832292 contact@porescale.co.uk www.porescale.co.uk Rho*V UK Ltd Dale Harger – Seismic Geophysicist Rho*V can effectively engage all aspects of seismic acquisition and processing projects. Services include; • Leader in high-definition, high trace density, low surface impact land 3D seismic survey design, • Seismic data acquisition/processing Project Management for land, streamer, and OBC surveys. • In-house bespoke 2D/3D seismic processing, • Specialist in refraction statics, noise attenuation, demultiple, 5D regularization, PSDM, and FWI, • Gather conditioning for QI analysis, • Geophysical research, • Contract tendering, evaluation, and supervision. Harger@RhovCo.com +447505901267 www.RhovCo.com www.linkedin.com/in/DaleHarger

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Stephen O’Connor – Global Geopressure Advice Geopressure advice for Exploration, Asset, Production and Development Teams The understanding of geopressure is a vital element when exploring the subsurface at all stages of exploration and exploitation. Whether assessing a basin, risking a prospect, preparing to drill, actively drilling or developing and producing an existing accumulation, Stephen brings together disciplines such basin studies; sedimentology, rock physics, structural geology and geomechanics to provide an integrated, holistic service aimed at provide variable levels of expert analysis to suit technical and budgetary requirements. This consultancy can also offer training courses for companies, whether off-the-shelf or bespoke such as tailored for asset teams and drilling. The development, design and implementation of a Best Practice approach to geopressure within a company can also be requested. +7920713609 oconnorstephen373@gmail.com globalgeopressureadvice.com (coming soon) SeisWise Ltd Christopher H. Walker Seismic Data Processing Consultant Contractor supervision; expert advice on reprocessing, trial processing, processing contracts; training courses. Over 40 years’ experience, MA (Cambridge, mathematics) MBA. 01234 771536 chris@seiswise.com www.seiswise.com

The world’s leading geoscience and multi-client data provider just got better. • Enhanced customer service • More G&G expertise under the same roof • Momentum for enhancing our imaging quality and proficiencies • From seismic to well data, more data and more coverage in all major mature and frontier basins worldwide • A robust data library and development of robust analytics solutions The gateway to subsurface intelligence.

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