OGV Energy - Issue 60 - September 2022 - Digital Transformation

SEPAUGUST 2022 - ISSUE 2020 60

UK’s No. ENERGY SECTOR

1

PUBLICATION

DIGITAL TRANSFORMATION

GLOBAL ENERGY NEWS WORLD PROJECTS MAP

FEATURING

RCP - BEKA associates Stena Drilling - CAN Group Norwell EDGE - Viewport3 asset55 - ZynQ360 AGR - TAAP

MONTHLY THEME INNOVATION & TECH RENEWABLES CONTRACT AWARDS ON THE MOVE DECOMMISSIONING STATS & ANALYTICS LEGAL & FINANCE EVENTS

RCP - control equipment and engineering support services specialists are proud to announce a partnership with BEKA associates acting as a value added reseller across the UK READ ON P.4 > www.rcpat.com

Digitize.

Collaborate.

Design.

Revolutionizing digital project delivery.

FieldTwin from FutureOn consumes and presents huge data sets into a highly-visual, digital 3D environment that is easy to navigate, manage and enhance with integrations.

This integrated digital workflow combined with the intuitive drag and drop design tool allows delivery of major projects to first energy faster.

FieldTwin supports multi-user collaboration around a single project digital twin. Instant project mapping from existing GIS servers, a workflow management toolkit, and enhanced assets efficiently aid the development of offshore projects, including wind and hybrid projects with emissions benchmarking. An open API offers true vendorneutral interoperability, enabling powerful digital twin solutions for any offshore project design and delivery.

FieldTwin models deliver value by increasing efficiency, reducing uncertainty while enhancing decision-making and project economics. futureon.com ©2022 FutureOn

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CONTENTS

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COVER SPONSOR P.04 OGV COMMUNITY NEWS P.08 GLOBAL ENERGY NEWS P.11 WORLD PROJECTS MAP P.20 04

08

MONTHLY THEME P.22

29

25

30

INNOVATION & TECH P.32 RENEWABLES P.36 CONTRACT AWARDS P.38 ON THE MOVE P.40

32

31

32

DECOMMISSIONING P.42 STATS & ANALYTICS P.44 LEGAL & FINANCE P.46

44

COMPANY NEWS P.48

46

EVENTS P.49 PEOPLE IN ENERGY P.50

KENNY DOOLEY MAIN EDITOR Welcome to the 60th issue of the OGV Energy publication, what started out as a promotional publication for Offshore Europe 2017 is now 5 years old and a leading publication in the energy sector.

We are delighted to be partnering with RCP for this issue, a company that has supported our brand from the very first issue and has now featured in 59 of 60 publications. In this issue RCP announce their partnership with BEKA associates, you can read all about the technology and their partnership on page 4.

WISH TO CONTRIBUTE TO NEXT MONTH'S PUBLICATION?

Contact us to submit your interest daniel.hyland@ogvenergy.co.uk

Other contributions this month on the theme of “Digital Transformation” come from Norwell EDGE, TAAP, FutureOn, Imrandd, Viewport3, AGR, CAN Group, asset55, ZynQ360 and Destec.

We also have global project news from the Energy Industries Council, analytics and insights from Westwood Global Energy Group and contract news from Infinity Partnership.

Finally, we would like to take this opportunity to thank everyone that has supported OGV over the past 5 years and look forward to working with you over the coming years.

Thanks again to our readers for all their support. Have a great month.

VIEW THE OGV MAGAZINE ONLINE AT www.ogv.energy/magazine

4

COVER SPONSOR

RCP - control equipment and engineering support services specialists are proud to announce a partnership with BEKA associates acting as a value added reseller across the UK. RCP’s Ben Knight considers this to be a perfect partnership not only acting as a reseller of their PAGEANT HMI but also RCP providing the software programming of the NEW PAGEANT HMI.

BEKA associates have introduced Pageant, a new intrinsically safe combined Operator Panel and Programmable Logic Controller with plug-in input and output modules allowing direct connection to hazardous area sensors. Its optional Modbus RTU port can transmit data to other equipment in the safe or hazardous area and also enables it to be used as a remote Modbus RTU display.

Pageant's state of the art, low power technology simplifies design and reduces the cost of providing operator displays and controls in a hazardous area. Multiple variables can be displayed simultaneously, plus eight touch switches with tricolour LED indicators significantly reduce panel space requirements. Intrinsic safety protection provides maximum safety and allows installation in almost any flammable gas or combustible dust atmosphere or Zone.

Display Instrumentation Intrinsically Safe and General Purpose

PAG

Loop

Mod

Univ

Featuring a 7 inch backlit trans-reflective display which can be read in all lighting conditions, the panel and all of the plug-in modules have Ex ia certification allowing installation in Zones 1, 2, 21 and 22. The IECEx, ATEX and UKCA certifications permit any combination of plug-in input and output modules to be fitted to the display without the need for additional certification. Plug-in input and output modules for interfacing 4/20mA currents, switch contacts, proximity detectors and pulse sources are already available and more are being developed for other sensors.

Set P

The PLC employs industry standard CODESYS® runtime software which complies with IEC 61131 allowing programming in five different languages. The software includes a wealth of features and function blocks such as PID control and is supplied with a lifetime licence. CODESYS runtime software is already installed in more than 1,500 different products worldwide. It is supported by extensive documentation, including video presentations, and will therefore already be familiar to many users.

Indic

The display, eight programmable touch buttons and eight programmable tricolour LEDs are mounted behind a 4mm thick toughened glass panel with a 316 stainless steel surround. The IP66 front is totally flat and easy to clean, making the Operator Panel ideal for petrochemical, pharmaceutical and distilling applications. The Operator Panel is lightweight and dissipates less than 5W making it easy to mount in instrument panels and enclosures.

Pageant Operator Panels have been designed to be powered by a BEKA Power Isolator which may be mounted in a safe area or in Zone 2. Two models are available, the BA212 for applications in IIA, IIB gases and dust atmospheres and the BA243 for IIC gas applications.

Rate

Coun

Tach

Time

Field

Flow

Soun LED

www.beka.co.uk PAGEANT IS Operator Panel

Tachometers

Loop Powered Indicators

Timers or Clocks

Modbus & Serial Data Displays

Fieldbus Indicators & Displays

Universal Process Panel Meters

Flow Batch Controllers

Set Point Stations [Generators]

Indicating Temperature Transmitters

Rate Totalisers

Sounders & Beacons

Counters

LED Cluster Lamps

www.beka.co.uk

www.ogv.energy I September 2022

RCP - ATEX and CE approved control equipment further enhance our portfolio, including choke control consoles, pump stroke counters and mud flow transmitters.

For more information visit rcpat.com

www.b

COVER SPONSOR

5

NEW

PAGEANT IntrInsIcally safe OperatOr panel

HMI, PLC, Modular I/O & Comms l

Intrinsic safety Ex ia certification allows installation in Zones 1, 2, 21 or 22

l

7 Inch backlit operator screen

l

IEC 61131 compliant PLC

l

Up to 7 plug-in input or output modules

l

8 touch buttons with tricolour annunciators

l

IP66 toughened glass and stainless steel front panel

l

3 year guarantee

www.beka.co.uk sales@beka.co.uk

Hitchin SG5 2DA UK +44 (0) 1462 438301

Editorial

newsdesk@ogvenergy.co.uk +44 (0) 1224 084 114

Advertising

office@ogvenergy.co.uk +44 (0) 1224 084 114

Design

Ben Mckay

Journalist

Tsvetana Paraskova

CONTRIBUTORS

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OGV COMMUNITY NEWS

support foundation designs and installation.

Fugro also engineered a full suite of purposely designed conductor casing handling devices to remove manual intervention, improving health and safety of deck crew and ensuring deployment efficiency within the short slack water windows.

Fugro develops innovative site investigation solution for Arklow Bank Wind Park

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New Offices & Team Expansion for Aberdeen-based Energy Sector Consultancy Prism Energy Prism Energy, an Aberdeen-based project & risk management consultancy to the energy sector has relocated from its Hill of Rubislaw office to 25 Rubislaw Terrace in Aberdeen city centre.

The team has seen an extensive period of contract wins/renewals in excess of £500,000 which has resulted in team growth and the requirement for larger premises. The team also welcome Mick Grimshaw as Project Management Consultant and Allan Urquhart as Project Manager.

World-leading Drilling Systems Delivers Bespoke Well Control Training Lab for US College World-leading provider of advanced drilling simulation technology, Drilling Systems, part of market-leading provider of training, technology and simulation solutions 3t Energy Group, has delivered a bespoke well control training lab to Western Texas College (WTC) with the installation of its cutting-edge simulators.

www.ogv.energy I September 2022

Wind Park Phase 2. This offshore wind park will support Ireland’s climate action target of producing 7 GW of offshore wind energy by 2030 and is located approximately 6 to 13 km off the coast of Ireland, in an area known for its unpredictable metocean conditions. Fugro developed a bespoke casing system designed for the offshore site conditions to enable survey work to be completed with minimal downtime. The acquired Geo-data will be used to understand the site’s subsurface conditions and

CAN Group Shortlisted for Prestigious Offshore Safety Awards CAN Group has been selected as a finalist in the Operational Integrity category in the prestigious 2022 Offshore Safety Awards, for its continued efforts in ensuring safe operations.

The market-leading life of asset integrity service company has been shortlisted for its innovative data intelligence solution, ENGAGE, that supports integrity needs across the full asset life cycle by connecting the dots between asset data and integrity to ensure safe and successful operations.

ZynQ 360 promotes Ewelina Witkowska to the Production Manager role Eve is just approaching her 4th anniversary with ZynQ 360 and during this time her skill set has developed beyond her original role.

“Eve’s continued keenness to learn, increased responsibility and involvement in the Production Management processes meant we saw this as a natural and well-deserved progression for her within the company”, commented Aly Gray, Operations Director.

Laboratory testing is currently underway, building on the site testing completed in Fugro’s offshore laboratory, allowing all acquired samples to be analysed efficiently with the resulting Geo-data used to inform foundation designs. When complete, the 800 MW wind park will be capable of powering almost 850, 000 homes with green energy and offset 830 billion kilograms of carbon emissions each year.

John O’Sullivan, SSE Renewables’ Arklow Bank Wind Park Phase 2 Project Manager said: “The successful completion of this ground investigation campaign is another key milestone for the Arklow project. It has enabled us to gain a much clearer understanding of the seabed conditions within the lease area. This enhanced site characterization greatly supports our ongoing design development works in the lead up to the first offshore energy auction.”

EthosEnergy nominated for Optimisation Award at the EIC Awards 2022 EthosEnergy has been shortlisted for the Optimisation category in the Energy Industries Council (EIC) Awards 2022, which recognizes companies who focus on improving internal decision-making, costs, processes, agility, structures, and enhancing competitiveness. This is the second consecutive year that the organisation has been shortlisted at the Energy Industries Council’s annual awards. Last year EthosEnergy took home the Culture Award after being recognised for exceptional business transformation.

Film-Ocean chooses Caledonia Competence for Competence Management Scheme support services ROV inspection and intervention services contractor, Film-Ocean, has awarded a contract to Caledonia Competence for the development and ongoing support of its Competence Management Scheme. The contract award includes the use of Caledonia Competence’s ATTAIN Competence Portal for all Competence Inductions and online assessments for Film-Ocean’s offshore workforce.

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ENERGY NEWS

11

SEPTEMBER 2022

UK NORTH SEA

Energy Review

By Tsvetana Paraskova

The windfall tax, higher gas production, energy security, and new field developments featured in the UK’s oil and gas industry last month.

The UK has cut its dependence on imported gas this year, according to figures shared by Offshore Energies UK, the leading representative body for the UK offshore energy industry. New figures show domestic gas production was 26% higher in the first half of 2022 compared to the same period in 2021, which is enough to heat almost 3.5 million UK homes for a year.

The UK has broken all energy links with Russia, with a recent House of Commons briefing confirming that in June 2022, the UK imported no oil, gas or coal from Russia. Gas is currently the backbone of the UK’s energy mix, meeting 44% of the country’s electricity generation in July and heating 85% of homes, as well as fuelling other industrial processes producing materials and goods, OEUK said at the end of August.

OEUK also warned the rapid reduction in UK supplies of gas would increase consumer costs further as it would decrease availability of international supplies and ramp up prices. It added that the current energy supply crisis demonstrates the challenges countries face if oil and gas production declines more rapidly than demand, with renewable electricity generation and alternative domestic heating sources such as hydrogen not yet available at the scale needed.

Jenny Stanning

“While we don’t know what winter will bring for the UK this year, we know that it is coming and, we must be prepared for the worst and hope for the best to support UK energy security,” said OEUK Sustainability Director Mike Tholen.

The offshore industry body urged in mid-August Conservative candidates to stand up for secure energy.

“While both Conservative party leadership candidates have stated their support for the sector, the ongoing speculation caused by recent calls to extend the tax is hurting places like Aberdeen which have a vibrant offshore energy industry,” OEUK External Relations Director Jenny Stanning said.

“We are clear that extending the windfall tax would make it even harder to attract investment that is badly needed to meet the UK’s energy needs,” Stanning added.

Continues >

UK NORTH SEA REVIEW

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ENERGY NEWS

UK NORTH SEA

A day earlier, OEUK said that new Labour proposals to extend the Energy Profits Levy would leave the UK facing decades of energy insecurity, heap further costs on consumers and risk making the nation ever more dependent on other countries for the gas and oil needed to keep the nation’s lights on, its homes warm and to fuel its transport system.

Commenting on the UK Government’s announcement that 20 projects were shortlisted for the next stage of its carbon capture, usage and storage (CCUS) cluster process, OEUK’s Energy Policy Manager Will Webster said: “This is just the start. We are going to need all of these projects, as well as the Scottish cluster and more, to support our ambition of capturing 2030 MtCO2 per year by 2030.”

“The highly ambitious 35% target was always intended to be challenging and the significant savings already delivered greatly benefit companies, which can invest more in production and emissions reduction projects, and taxpayers by reducing the cost of decommissioning tax reliefs to the Exchequer,” NSTA said.

Pauline Innes

OEUK launched at the end of July a survey to help measure the diversity of its members’ workforce as it continues to drive greater diversity and inclusivity in the industry.

This is essential to support energy security and the transition to greener energies, the industry body said.

OEUK also published on 11 August new guidelines to help oil and gas companies reduce methane emissions from the production of oil and gas. The guidelines come as OEUK implements its Methane Action Plan (MAP) – a core deliverable of the 2021 North Sea Transition Deal between the UK Government and the offshore oil and gas industry. The MAP commits the sector to halve its methane emissions by 2030, compared to 2018, and adopt the Oil and Gas Climate Initiative (OGCI) methane intensity target of 0.25% by 2025. It also recommended companies and offshore installations put in place their own plans of action by the end of 2023.

Crown Estate Scotland, Marine Management Organisation, the Marine Scotland Directorate of the Scottish Government, North Sea Transition Authority (NSTA), Ofgem, and The Crown Estate created the Offshore Energy Digital Strategy Group (DSG), which held its first meeting at the end of July.

Decommissioning Cost Estimate Report 2022, which showed that the cost of decommissioning oil and gas infrastructure has been cut by 25% in the past five years. The forecast fell by £1.5 billion (or 2%) to £44.5bn last year – contributing to a total cut of £15 billion (25%) since 2017, when the NSTA introduced a baseline estimate of £59.7 billion and set a target of reducing costs by 35% to £39 billion by end-2022.

Pauline Innes, NSTA Head of Decommissioning, said:

delivered in two phases. Subsea installation will begin in 2024 comprising three installations seasons 2024, 2025, and 2026.

From first production in 2026 through to 2030 Rosebank could account for around 8% of the UK’s oil production, according to Equinor’s estimates. Rosebank, which will be tied to the UK gas infrastructure, is projected to produce an average of 21 MMSCF of natural gas every day, equivalent to the daily average use of Aberdeen city.

Neptune Energy began on 24 August an infill drilling campaign at its operated Cygnus gas field in the southern North Sea, with the potential to unlock enough gas to heat an additional 200,000 UK homes per year from this winter.

Serica Energy said in early August it does not intend to make an offer for Kistos. In July Kistos had rejected a possible offer from Serica, and subsequently it has not been possible to reach an agreement with Kistos on the terms or structure of a revised possible offer, Serica added.

“The decommissioning market is worth tens of billions of pounds in the UK alone. Our industry is demonstrating that it can complete projects safely, efficiently and economically in the North Sea, and that places it in a strong position to compete for what is a big international prize.”

Deltic Energy announced at the end of July that it and its joint venture partner Shell made a positive well investment decision to drill the high impact Selene Gas Prospect in the UK Southern North Sea off the North East coast of England.

“The sector must not lose focus and allow inflation to drive up prices. Now is the time to build on the progress already made,” Innes added.

i3 Energy has completed the farmout of a 25% working interest in Block 13/23c North, which contains the Serenity discovery, to Europa Oil and Gas Limited. Europa will fund 46.25% of the cost of the upcoming Serenity appraisal well up to a gross capped well cost of £15 million.

In company and field development news, Shell has taken the final investment decision (FID) to develop the Jackdaw gas field in the UK North Sea, following regulatory approval earlier this year. Jackdaw will comprise a wellhead platform that is not permanently attended, along with subsea infrastructure which will tie back to Shell’s existing Shearwater gas hub.

The project is expected to come online in the mid-2020s, and at peak production rates, could represent over 6% of projected UK North Sea gas production in the middle of this decade, with operational emissions of less than 1% of the whole UK basin.

Nic Granger That is enough energy to heat 1.4 million homes.

Orcadian Energy has executed a formal agreement with Carrick Resources to farm out a licence that includes the Carra prospect to the East of the Crinan and Dandy discoveries and to the South of Fyne. Carra is undrilled and unexplored but early, internal estimates from Carrick indicate there is the potential for it to contain P50 recoverable prospective resources of 30 MMbbls of medium gravity oil.

The group started off the project of maximising North Sea potential by bringing together leading organisations to combine their data and digital efforts.

Aker Solutions has been awarded a contract from Shell UK for the delivery of the not permanently attended installation (NPAI) for the Jackdaw gas field.

Deltic Energy said in its interim results for the first half of 2022 that it had made excellent progress in maturing the recently awarded Syros prospect on Licence P2542 in the Central North Sea. Following analysis of seismic data, Deltic Energy now considers Syros to be a low risk prospect with estimated P50 prospective resources of 24.5 mmboe and a 58% geological chance of success. Syros also sits in close proximity to existing infrastructure with multiple offtake opportunities which would allow it to be quickly and easily developed. Deltic Energy is in the process of launching a farm out process with the aim of introducing a partner to drill this prospect.

“This is an exciting project which brings together key organisations working alongside each other in the North Sea to unlock maximum value from data and digital,” Nic Granger, NSTA Director of Corporate, said.

In early August, Equinor submitted to UK authorities its environmental assessment for the Rosebank oil and gas field in the FaroeShetland Channel on the north-west edge of the UK Continental Shelf (UKCS). The project, from which first oil is currently expected for the fourth quarter of 2026, is planned to be

IOG plc targets first gas from Southwark in Q4 2022. Subsea, hook-up, and commissioning works are ongoing, the company said at the end of August in its half-year report. The Goddard and Kelham North/Central appraisal wells will be drilled in direct continuation after Southwark, IOG added.

NSTA published in early August its

www.ogv.energy I September 2022

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BRENT OIL PRICES OVER THE YEARS September Review

THE SOCIAL STRATEGIST

1

YEAR AGO

Eric Doyle

Planning for a Sales and Marketing redesign in the Digital Transformation

By Eric Doyle

We meet some amazing leadership teams from a wide variety of sectors and geographic locations, and it is astonishing how different, even companies in the same sector, approach demand generation.

Regardless of the size of our companies, we are all looking for the same thing…

1. Access to markets: Getting to the heart of markets, deep understanding, and presence.

2. Credibility in those markets: We are understood and appreciated in the right places by the right people.

3. Meaningful connection with prospects: A real relationship, beyond brochures.

4. Commercial interaction: Turning all of this into purchase orders and revenue This it, the Holy Grail, it’s what we all want in some way, shape of form, regardless of whether we are a 250K turnover company or a 250M turnover company.

The way different organisations go about securing this is interesting.

There are those that are very advanced in all the due diligence of mapping out and applying their new routes to market, with diverse and encompassing digital strategies and internals plays. A particular company comes to mind, who are remapping their entire management system to incorporate a digital ‘lead to purchase order’ system designed to accommodate Social Selling & Influence. This is a business that was completely analogue in their thinking about demand generation, they thought it was all about cold calling, email, and adverts.

There are those at the opposite side of the scale that are still trying to use outdated methods to pick up leads with new prospects, get on calls, set up meetings and hope for the best. They have heard about digital transformation but dismiss it something not applicable to them… “But Eric, we are an engineering company, does this apply to us...?”

Then there is the middle ground, no man’s land. Here we find those that are fumbling around trying to make it up. They will tell us they are all over it…, “we are all over Social”, at some point usually someone tells me how many followers they have on their company page on LinkedIn…when I turn the discussion

to how they’ve monetised being “all over Social” and the tone changes.

The win isn’t posting page after page of content…the win is being able to consistently apply a process that you can convert into commercial interaction (see step 4 above).

You may not know about it or even understand it but there are areas on Social devoted to exactly what you and your company do, you should be leading that conversation.

This puts you in a such a different place that one of our clients recently described it as “an unfair advantage…”

There is a ‘Digital share of voice’ for your sector…who owns yours...?

Who are the leading Technical and Commercial digital influencers in your sector...?

Both answers should be you…

How to make sure your business is on the right side as the Digital Divide grows ever wider… and how to stay there.

Gartner are giving us all the clues for free!

“80% of b2b transactions will be completely digital by 2025”,

- BRENT OIL PRICE 2021 - $72.97 A study found that the vast majority of fossil fuel reserves owned by countries and companies must not be extracted if the climate crisis is to end. The research found that 90% of coal and 60% of oil and gas reserves could not be removed if there was to be even a 50% chance of keeping global heating below 1.5C.

5

YEARS AGO

- BRENT OIL PRICE 2017 - $55.16 The brent oil price continued to rise into September and seen prices reaching a two-year high. BP’s top oil trader in Asia said the crude market had turned a corner after a three-year slump, with consumption boosted by lower prices and excess inventories finally declining thanks to OPEC’s efforts to cut production.

“33% of buyers don’t ever want to see your Sales team”, “We need to be changing our Sales Motions to match modern Buying Motions…”

I run a B2B business just like you and all that we do in terms of strategy and preparation is in line with this.

This isn’t relevant only to the Tech industry or people in Digital Marketing, this a current issue for all B2B businesses…yours and mine.

Waiting for ‘things to go back to normal’ at this stage is futile and damaging to our futures.

3 questions to ask your team today: Who are the leading technical and commercial digital influencers in our sector?

Does our strategy for Social Media stretch beyond the marketing team?

Can we link our Social Media activity to elements of our pipeline?

These are board level discussion points for all B2B businesses in the energy sectors today.

The discussion about whether this ‘works or not’ is over, it’s now time to get your people trained and expert in digital networking, prospecting, building influence and closing business generated from the application of your Social Selling & influence strategy.

Eric is a Co-Founder of Crux Consultancy Limited who train and coach cross sector B2B teams in the art and science of Strategic Social Media through Social Selling & Influence. www.consultcrux.com

10

YEARS AGO

- BRENT OIL PRICE 2012 - $114.86 The Arctic had often been seen as the promised land by oil companies but according to a study it would only be likely to play a marginal role in providing the planet’s future energy needs.

Shell had hoped its Arctic campaign would be a showcase for their technological prowess, but the programme had failed to take off. The oil giants planned to drill five Arctic wells in the summer of 2012 but then cut that down to two in July, and then in September decided they will not complete any.

14

ENERGY NEWS

ENERGY NEWS

Europe

Energy Review

By Tsvetana Paraskova

By Tsvetana Paraskova

(Photo: Kristian Helgesen)

Heightened uncertainty over Russia’s pipeline gas supply to Europe, soaring gas and power prices, a major gas discovery, development plans for oil and gas fields offshore Norway, and a lot of investment in clean energy projects have been the key themes in the European energy industry in recent weeks.

Oil & Gas Russia continued to keep gas flows to Europe via Nord Stream at low levels after the maintenance on the pipeline ended at the end of July. Since 24 July, Gazprom has been sending gas at just 20 percent of the pipeline’s capacity and further warned in the middle of August that all flows through Nord Stream would be halted for three days between 31 August and 2 September.

European officials are concerned that flows could be further reduced after 2 September or stopped altogether, which stoked another rally in Europe’s natural gas and electricity prices to fresh records.

www.ogv.energy I September 2022

At the same time European companies are drilling for more gas and oil offshore Norway, proposed new field developments, and made a massive gas discovery offshore Cyprus.

Italy’s Eni, operator of Block 6 off Cyprus, announced on 22 August a significant gas discovery, with preliminary estimates pointing to about 2.5 TCF of gas in place.

“The discovery paves the way for the development of new gas resources in the Mediterranean region and is part of Eni's successful efforts to support the supply of additional energy to Europe,” the Italian company said.

Neptune Energy began drilling at the end of July at the Ofelia exploration well in the Norwegian sector of the North Sea. In case of a commercial discovery, the Ofelia prospect could be tied back to the Neptuneoperated Gjøa platform and produce at less than half the average carbon intensity of Norwegian Continental Shelf fields.

At the end of August, Neptune Energy and its partners announced a new commercial discovery at the Ofelia exploration well and encountered oil in the Agat formation. The preliminary estimate of recoverable volume is in the range of 16-39 million barrels of oil equivalent. In addition to the Agat volumes, north of the well there is an upside of around 10 million boe recoverable gas in the shallower Kyrre formation, which brings the total recoverable volume to approximately 26-49 million boe.

Neptune Energy also announced the safe and successful drilling of four development wells on the operated Fenja field in the Norwegian

Sea, in preparation for production start-up.

Fenja is scheduled to come on stream in the first quarter of 2023 and will produce around 28,000 barrels of oil equivalent per day (boepd) at plateau.

Wintershall Dea has started production from the Nova oil field in the Norwegian North Sea, which comes on stream at a time where Europe needs every additional barrel it can get.

Sval Energi signed in early August an agreement with Suncor Energy to acquire Suncor Energy Norge AS. “The Norwegian Continental Shelf is still attractive, and we are building a strong cashgenerating business in Norway with producing assets, future developments, and exciting exploration opportunities. We are executing our strategy and transforming into a significant player on the Norwegian Shelf,” Sval Energi CEO Nikolai Lyngø said.

Vår Energi has increased its acreage positions offshore Norway and took new operatorship in the Balder area through several transactions.

“We have a long-term, hub-oriented growth strategy in the North Sea, and these acquisitions add new opportunities to an already robust portfolio. The acquired licenses will be worked as part of further development of the greater Balder area,” said VP Field development & Projects in Vår Energi, Bjørn Thore Ribesen.

Aker BP and its partners submitted in early August a plan for development and operation for Trell & Trine in the Alvheim area of the North Sea.

EUROPE “From an operational perspective, the Alvheim area is one of the most costeffective on the Norwegian shelf, and the resource base has expanded dramatically since the field came on stream,” Aker BP CEO Karl Johnny Hersvik said.

Aker BP also awarded Subsea 7 a sizeable contract for the Trell & Trine field development. The project involves a subsea tie-back of around 21 kilometres to the Alvheim FPSO, via the existing East Kameleon subsea manifold.

Aker Solutions has also been awarded a contract from Aker BP to provide the subsea production system for Trell & Trine. Aker Solutions will deliver a subsea production system including three horizontal subsea trees, two manifolds, control systems, close to 30 kilometres of subsea umbilicals, as well as associated equipment and installation work. The work will start immediately with final deliveries scheduled for the first quarter of 2024.

Low Carbon Energy In low-carbon energy solutions in Europe, Crown Estate Scotland opened on 10 August the Innovation and Targeted Oil and Gas (INTOG) offshore wind leasing process.

Under the leasing round, offshore wind developers are being invited to put forward projects for the rights to build small-scale innovative offshore wind projects, of less than 100 MW, and projects which will provide green electricity to oil and gas infrastructure to reduce their carbon emissions.

OEUK welcomed the new wind leasing round in Scotland, with OEUK’s Energy Policy Manager, Will Webster, saying: “Integration of offshore wind production with our vital oil and gas facilities means we can reduce emissions from production, ensure the industry remains a reliable and clean energy partner during the transition, and accelerate the drive to a more sustainable future.”

Later in August, Crown Estate Scotland said that three projects would be offered seabed agreements for offshore wind projects following Crown Estate Scotland’s ScotWind clearing process. The three projects selected are all floating and are expected to generate 2.8 GW of electricity once operational.

“Taking these three into account, the 20 ScotWind projects now total up to 27.6GW with initial supply chain commitments indicating an average of £1.4bn investment in Scotland per gigawatt of capacity built,” Colin Palmer, Director of Marine at Crown Estate Scotland, said.

The rise in the UK Energy price cap shows an urgent need to switch to renewables faster, RenewableUK said, commenting on Ofgem’s announcement at the end of August.

“Let's be absolutely clear - the cause of this unaffordable increase in household bills is the cost of gas. So we urgently need to see a greater level of emergency support for consumers from the Government to get through the winter, and we need to switch to low-cost alternatives much faster,” said RenewableUK’s Chief Executive Dan McGrail.

TotalEnergies and its partner SSE Renewables announced on 23 August first power generation from the Seagreen offshore wind farm, 27 kilometres off the coast of Angus in Scotland.

ScottishPower Renewables started onshore construction for East Anglia THREE offshore wind farm. Part of the East Anglia Hub, East Anglia THREE will have a capacity of 1,400 MW of green electricity – enough to power around 1.3 million homes.

Investment and asset manager Downing LLP said it had been selected by Yorkshire Water to develop, design, build, and operate a portfolio of 28 solar sites across Yorkshire. The first phase of solar deployments, an investment worth around £25 million, will generate a total capacity of approximately 21 MW. bp said on 1 August it planned to invest up to £50 million in a new, state-of-the-art electric vehicle (EV) battery testing centre and analytical laboratory in the UK. bp has previously announced its intention to invest up to £18 billion in the UK’s energy system by the end of 2030, and this additional new investment is a further example of bp’s commitment to the country, the supermajor said.

Renewable energy development investor Magnora has entered the UK solar and battery storage services market by investing in the development of a 60 MW solar PV project and a 40 MWh Battery Energy Storage System (BESS) project, as a first step.

“We will continue to monitor further opportunities, and subject to a successful development in this first step, we will consider further investments in the UK solar PV and BESS market,” said Erik Sneve, CEO of Magnora ASA.

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Network Rail has signed an agreement with EDF Renewables UK which will see enough solar energy to power 20,000 homes used in offices, depots and railway stations across the UK. Stillstrom by Maersk, a newly launched offshore charging company, has announced that it will collaborate with Port of Aberdeen on a pioneering project to significantly reduce emissions from vessels on standby outside the port. Stillstrom and Port of Aberdeen will conduct a joint feasibility study into an innovative offshore renewable charging hub.

Spain’s Iberdrola has put into operation the 'Francisco Pizarro' project in Extremadura, the largest photovoltaic plant in Europe and the largest facility of this type operated by the group in the world. The plant has an installed capacity of 590 MW. Iberdrola has also signed an agreement with bp to collaborate to accelerate EV charging infrastructure and green hydrogen production.

Together, the companies intend to collaborate to significantly expand fast EV public charging infrastructure, as well as to develop large scale green hydrogen production hubs in Spain, Portugal, and the UK. bp has also opened its first ultra-fast-charging facilities aimed at medium and heavy-duty electric trucks to support the decarbonisation of the sector. The retail site at Schwegenheim in Rheinland-Pfalz, Germany, now has two stateof-the-art 300kw ultra-fast chargers intended for electric trucks, powered by 100% renewable energy, bp said.

A consortium of TotalEnergies, Corio Generation, and Qair has been pre-selected by the French Directorate General for Energy and Climate (DGEC) to participate in a competitive tender to develop two floating wind farms in the Mediterranean Sea. The two projects of about 250 MW each could supply enough clean energy to meet the annual electricity consumption of almost one million people, TotalEnergies said in early August.

Wintershall Dea and Nord-West Oelleitung (NWO) will collaborate on Wintershall Dea's BlueHyNow project, part of the EnergyHub currently under construction in Wilhelmshaven, Germany. Wintershall Dea plans to build a plant for the production of large volumes of low-carbon hydrogen using Norwegian natural gas. The hydrogen produced can be delivered by pipeline to industrial customers for use as a decarbonised energy source or as a raw material, reducing their CO2 emissions.

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long-term certainty to the renewables sector, with solar power a major beneficiary, Seiple said.

Clean hydrogen, EV uptake, and wind power installations are also set to accelerate under the IRA. The law will also unlock over $160 billion of investment in energy storage through 2031, with energy storage forecast to soar to 135 GW in ten years’ time, according to WoodMac estimates.

“Later this year at the G20 and COP27 meetings, the US will gain new credibility as a global leader on climate change. With the wind at its back, the nation can encourage the world to expand policy goals that reach for a net zero emissions pathway,” Seiple said.

US

Still, per Rystad Energy research, there could be significant growing pains in the coming years for the clean energy industry in the United States.

ENERGY REVIEW

The Inflation Reduction Act and its implications for the US oil and gas sector was the highlight of the past month in the American energy industry, where the oilfield services sector added more jobs for a ninth month in a row and where high liquefied natural gas exports made the United States the world’s top LNG exporter.

www.ogv.energy I September 2022

“Contrary to its title, the US Inflation Reduction Act will usher in more energy service inflation in the next 18 months as the incentives offered to manufacturers struggle to keep up with the increased demand triggered by the bill,” the independent energy research firm said days before the bill became law.

Inflation Reduction Act US President Joe Biden signed in August the Inflation Reduction Act which is aimed at lowering costs for families, fighting climate change, reducing the deficit, and finally asking the largest corporations to pay their fair share, the White House says.

The legislation seeks to reduce greenhouse gas emissions by about 1 gigatonne in 2030, or a billion metric tons, as well as deploy clean energy and reduce particle pollution from fossil fuels.

According to Wood Mackenzie, the Inflation Reduction Act will accelerate decarbonisation, with over $300 billion allocated to spur investments in zero-carbon power generation supply, emissions reduction technology, and electrification and energy efficiency programmes. The legislation is expected to spark a boom in decarbonisation technologies over the next ten years, says Chris Seiple, Vice Chairman, Energy Transition and Power & Renewables, at WoodMac. The Inflation Reduction Act (IRA) will bring much-needed

“There will be a positive impact on domestic energy security and the US’ position in the global low-carbon supply chain, but significant growing pains are likely in the coming years,” Rystad Energy reckons.

“Cost inflation in the US energy industry has hit operators, manufacturers and suppliers hard – and the Inflation Reduction Act shows no signs of addressing that in the near term,” said Matthew Fitzsimmons, senior vice president with Rystad Energy.

“The fate of the industry’s future inflation or deflation lies firmly in the hands of the Chinese, fittingly, as US policymakers attempt to build and strengthen a domestic supply chain and attempt to avoid such reliance in the future,” Fitzsimmons noted.

The Inflation Reduction Act could also pose new challenges to recruitment in the oil and gas industry, Rystad says.

The number of unemployed American workers actively looking for oil and gas jobs has been at its lowest since 2005.

US

17

“While previous wage premiums have saved the day and enticed workers to help grow domestic oil and gas production previously, the bill will pose new competitive challenges for oil and gas recruitment,” the research firm adds.

Employment in the US oilfield services and equipment sector rose by an estimated 7,131 jobs to 643,092 in July, preliminary data from the Bureau of Labor Statistics (BLS) and analysis by the Energy Workforce & Technology Council showed in early August.

Oil & Gas Industry Criticises Inflation Reduction Act

The data reported is the highest since September 2021 when total jobs rebounded to 643,057, but still off the pre-pandemic mark in February 2020 of 706,528.

While analysts expect the clean energy sector to be a major beneficiary of the legislation, the biggest oil lobby said the Inflation Reduction Act fell short of addressing America’s long-term energy needs and imposed more costs on households.

“While the Inflation Reduction Act takes important steps toward new oil and gas leasing and investments in carbon capture and storage, it falls well short of addressing America’s long-term energy needs and further discourages needed investment in oil and gas,” American Petroleum Institute (API) President and CEO Mike Sommers said.

“API shares the goal of addressing climate change, as evidenced in the policies we support and in the actions that our industry is taking every day. However, the considerable tax increases are simply the wrong policies at the wrong time,” Sommers added.

“From a new corporate minimum tax to an $11.7 billion tax on crude oil and petroleum products to a new natural gas tax, this legislation imposes additional costs on American families and businesses at a time when policymakers should be looking for solutions to provide relief.”

“While the Inflation Reduction Act takes important steps toward new oil and gas leasing and investments in carbon capture and storage, it falls well short of addressing America’s long-term energy needs and further discourages needed investment in oil and gas,” said American Petroleum Institute (API) President and CEO Mike Sommers.

“The July job increases are very encouraging as our sector continues to rebuild the workforce from pandemic losses. Our industry is meeting the challenge of growing global demand by producing at almost pre-pandemic levels, reducing emissions industry wide, all while continuing to make gains in the workforce,” said Leslie Beyer, CEO, Energy Workforce & Technology Council.

In Texas, job growth in the upstream sector continued in July, with upstream employment in the biggest oil-producing state in the US topping 200,000 for the first time since March 2020, the Texas Oil and Gas Association (TXOGA) said on 19 August, citing data from the Texas Workforce Commission.

Texas’s upstream oil and natural gas employment grew in July by 6,800 jobs from June, the second highest monthly increase in data history since Texas Workforce Commission’s online data became available to the public in 1990, TXOGA said.

According to Sommers, the bill also fails to address permitting reform, which API views as essential to effectively delivering affordable, reliable energy to consumers in a growing economy.

Since the low point in employment September of 2020, the oil and gas industry has added 45,800 upstream jobs in Texas. At 202,800 upstream jobs, July 2022 jobs were up by 35,400 – or 21.1% – from July 2021. Employment in July 2022 topped 200,000 jobs for the first time since March of 2020, TXOGA noted.

US Shale Set for $10 Billion Losses from Hedging

The US Becomes World’s Largest LNG Exporter

US shale producers that have hedged output at lower prices last year are expected to lose from the derivative hedging if oil prices stay around $100 per barrel, Rystad Energy research showed in the middle of August.

Derivative hedging losses could be more than more than $10 billion, the energy intelligence firm says.

High demand for LNG, especially in Europe, high gas and LNG prices globally, and increased US export capacity made the United States the world’s largest LNG exporter in the first half of 2022, the US Energy Information Administration (EIA) said at the end of July.

“Those who hedged at lower prices last year are in line to suffer significant associated losses as their contracts mean they cannot capitalize on sky-high prices,” Rystad Energy reckons.

Still, despite the hedging losses, cash flows and net earnings hit record highs at many shale producers in the second quarter, Rystad Energy notes.

“With huge losses on the table, operators have been frantically adapting their hedging strategies to minimize losses this year and next. As a result, we may not have seen peak cash flow in the industry yet, which is hard to believe given the soaring financials reported in recent weeks,” said Rystad Energy Vice President Alisa Lukash.

Employment in US Oil & Gas Sector Continues To Rise Meanwhile, employment in the US oil and gas industry continues to grow, per the latest statistics and industry estimates.

“With huge losses on the table, operators have been frantically adapting their hedging strategies to minimize losses this year and next. As a result, we may not have seen peak cash flow in the industry yet, which is hard to believe given the soaring financials reported in recent weeks,” said Rystad Energy Vce President Alisa Lukash

US LNG exports rose by 12% in the first half of 2022 compared with the second half of 2021, averaging 11.2 billion cubic feet per day (Bcf/d), the EIA said.

During the first five months of 2022, most US LNG exports went to the EU and the UK, accounting for 64%, or 7.3 Bcf/d, of the total US LNG exports, the US administration noted.

Commenting on the news, Tim Tarpley, SVP Government Affairs & Counsel for the Energy Workforce & Technology Council, wrote in an analysis about the prospects of US LNG exports in light of Russia’s cuts in pipeline gas supply to Europe.

“This weaponization of gas means that our allies in Europe continue to look for reliable and long-term sources of gas to power their economies and keep their populations warm as winter descends on Europe. This situation presents an opportunity for the United States to open up a huge market for LNG that will sustain itself for many years.”

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ENERGY NEWS

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MIDDLE EAST Energy Review

By Tsvetana Paraskova

The OPEC+ group’s decision to slightly raise production targets in September, the recordsmashing profit of the world’s largest oil company, Saudi Aramco, and business deals involving the biggest energy firms in the Middle East were the highlights in the region’s oil and gas industry this past month.

OPEC+ Approves Symbolic Increase in Production Target At a regular monthly meeting on 3 August, the OPEC+ group approved a decision to raise their collective oil production target for September by 100,000 barrels per day (bpd). The August meeting was the first meeting since the alliance decided earlier this year to roll back by the end of August all the cuts from May 2020, when the current agreement started.

“The Meeting noted that the severely limited availability of excess capacity necessitates utilizing it with great caution in response to severe supply disruptions,” OPEC said in a statement after the OPEC+ meeting.

www.ogv.energy I September 2022

According to a production schedule shared

by OPEC, Saudi Arabia, the world’s top crude oil exporter and largest OPEC producer, has a target of pumping just over 11 million bpd—11.03 million bpd, in September. The same target applies to Russia, but Moscow has struggled to keep up with its quota since March, when the invasion of Ukraine and the Western sanctions and embargoes on Russian oil stymied production growth.

Reports and estimates put current Russian production at the levels from February 2022, meaning that output has rebounded from the lows in March and April but hasn’t increased in lockstep with the Russian target in the OPEC+ deal.

Alongside low Russian production, a lack of investment and capacity at many other OPEC+ members suggests that the group will not come anywhere close to pumping to target. Some of the latest estimates put the OPEC+ total crude oil production in July at 2.9 million bpd below the collective quota.

The gap between overall quota and actual oil production from the OPEC+ members has been growing for more than a year and is set to further grow in August and September as the target is being raised while many producers struggle to keep up with their respective quotas.

OPEC Cuts Oil Demand Estimate for 2022 In its Monthly Oil Market Report (MOMR) in August, OPEC revised down its global oil demand growth estimate for this year by 260,000 bpd, due to ongoing geopolitical tensions and possible new COVID-related restrictions in the second half of 2022.

OPEC expects global oil demand to grow by 3.1 million bpd this year, down by 260,000 bpd from the July assessment of 3.36 million bpd growth.

Demand is still expected to show “healthy growth of 3.1 mb/d, including the recently observed trend of burning more crude in power generation,” OPEC said in its report.

The organisation left its 2023 demand growth estimate unchanged from the July report at 2.7 million bpd. Total world oil demand is expected to reach 102.72 million bpd next year.

“In 2023, expectations for healthy global economic growth, combined with expected improvements in the containment of COVID-19 in China, are expected to boost consumption of oil,” OPEC said.

MIDDLE EAST Saudi Aramco Books Record Profit As Oil Rallies Saudi Aramco, the largest oil company in the world in terms of both production and market capitalisation, reported in mid-August record profits for the second quarter of 2022, driven by high oil and gas prices and increased production.

The Saudi state oil giant booked a net income of $48.4 billion for Q2, up by 90% compared to the same period of 2021. The increase was primarily driven by higher crude oil prices and volumes sold, as well as strong refining margins during the second quarter and higher downstream margins in the first half of 2022, Aramco said.

Higher cash from operating activities pushed free cash flow up by 53% to $34.6 billion in the second quarter compared to Q2 2021.

Aramco declared a dividend of $18.8 billion for the second quarter, to be paid in Q3 2022, the firm said, noting that it “aims to maintain a sustainable and progressive dividend in line with future prospects and underlying financial results.”

Deals & Contracts Apart from reporting record earnings, Aramco also announced several deals in August.

The Saudi company signed an equity purchase agreement to acquire Valvoline’s global products business for $2.65 billion.

Aramco expects to benefit from Valvoline Global Products’ robust manufacturing and distribution network, significant R&D capabilities, strong partnerships with major OEMs, and a 150-year legacy of global brand recognition as it pursues opportunities to extend the brand globally. The deal is subject to customary closing conditions, including the receipt of regulatory approvals.

Saudi Aramco also signed a Memorandum of Understanding (MoU) with China Petroleum & Chemical Corporation (Sinopec) covering multiple areas of potential collaboration in

In the United Arab Emirates (UAE), Abu Dhabi National Oil Company (ADNOC) announced several contracts, orders, and a discovery between the end of July and the end of August.

ADNOC awarded two substantial contracts totalling $2 billion (AED 7.49 billion) to ADNOC Drilling for the Hail and Ghasha Development Project. The contracts comprise $1.3 billion for integrated drilling services and fluids, and $711 million for the provision of four Island Drilling Units. A third contract, valued at $681 million, was also awarded to ADNOC Logistics & Services for the provision of offshore logistics and marine support services.

The Hail and Ghasha Development Project is part of the Ghasha Concession – the world’s largest offshore sour gas development and a key part of ADNOC’s integrated gas plan and the UAE’s efforts to become self-sufficient in gas.

ADNOC Logistics & Services, ADNOC’s shipping and maritime logistics arm, announced the acquisition of Zakher Marine International (ZMI), an Abu Dhabi-based owner and Aramco President and CEO Amin Nassera (REUTERS/Ahmaed Yosri/File Photo) operator of offshore support vessels, with the world’s largest fleet of self-propelled jack-up barges. Upon completion of the transaction, which is subject to customary regulatory approvals, ADNOC L&S will add 24 jack-up barges and 38 offshore support vessels from ZMI, growing its total fleet size to over 300 units.

ADNOC also awarded two contracts totalling more than $3.4 billion to ADNOC Drilling to hire 8 jack-up offshore rigs, which will support the expansion of ADNOC’s crude oil production capacity to 5 million bpd by 2030 and enable gas self-sufficiency for the UAE.

Capital expenditure at the Saudi oil giant rose by 25% to $9.4 billion in the second quarter and by 8% to $16.9 billion for the first half of 2022, compared to the same periods in 2021.

“Aramco continues to invest to capture growth opportunities, progressing the strategic integration of its upstream and downstream segments, expanding its chemicals business, and developing prospects in low-carbon businesses,” the company said.

Commenting on the results, Aramco President and CEO Amin Nasser said: “While global market volatility and economic uncertainty remain, events during the first half of this year support our view that ongoing investment in our industry is essential — both to help ensure markets remain well supplied and to facilitate an orderly energy transition.”

“In fact, we expect oil demand to continue to grow for the rest of the decade, despite downward economic pressures on shortterm global forecasts,” the top executive added, reiterating a long-held view in Saudi Arabia that oil will continue to play an important role in global energy supply for decades to come.

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Saudi Arabia. The scope of the potential collaboration includes assessing refining and petrochemical integration opportunities; engineering, procurement and construction; oilfield services, upstream and downstream technologies, as well as collaboration across carbon capture and hydrogen processes.

Aramco and SABIC Agri-Nutrients Company have obtained the world’s first independent certifications recognizing “blue” hydrogen and ammonia production, the Saudi company said in early August. The certifications were granted by Germanybased independent testing, inspection, and certification agency TÜV Rheinland to SABIC Agri-Nutrients Company in Jubail, for 37,800 tonnes of “blue” ammonia and to Aramco’s wholly-owned refinery (SASREF), also in Jubail, for 8,075 tonnes of “blue” hydrogen. To certify ammonia and hydrogen as “blue”, a significant part of the CO2 associated with the manufacturing process needs to be captured and utilized in downstream applications.

Furthermore, ADNOC announced a $1.17-billion contract for the hire of 13 self-propelled jack-up barges to support its plans to grow production capacity.

Finally, ADNOC announced a second natural gas discovery in the first exploration well in Abu Dhabi’s Offshore Block 2 Exploration Concession, operated by Italy’s Eni. The discovery from a new deeper reservoir indicates between 1 – 1.5 trillion standard cubic feet (TSCF) of raw gas in place.

In Qatar, McDermott International has been awarded a Front-End Engineering Design (FEED) contract by QatarEnergy for the North Field South (NFS) Offshore Pipelines and Power/FO cables Project.

The NFS infrastructure is part of the North Field Expansion Project (NFXP) development and is designed to supply feed gas for two additional LNG trains that would help increase total LNG production in Qatar from the current 77 million tons per annum (MTPA) to 126 MTPA.

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WORLD PROJECTS

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WORLD PROJECTS MAP 8 3

8 12

5 10 6 1

2 4

9

11 7 8

NIGERIA

1

Bonga North Tranche 1 – OML 118 Shell

$3.9 billion Expressions of interest for three EPC packages have been submitted and the prequalification process is currently underway. The three contracts cover: modification of an FPSO and integrating the FPSO with subsea umbilical, flowlines and risers: delivery of the SURF package; subsea equipment.

CAMEROON

NETHERLANDS

3

INDONESIA

Holland Hydrogen I

Timpan-1 Gas Discovery

$150 million

$200 million

$250 million

Tower Resources

Tower Resources are looking to drill the NJOM-3 appraisal well by the end of 2022. If the drilling goes ahead and is deemed successful, a decision will be made regarding three wells that are set to be drilled in Q1 2023, before contracts are awarded for the MOPU and the small platform set to beused. First production is planned for 2024 and will subsequently be followed by further drilling campaigns.

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www.eicdatastream.the-eic.com

www.ogv.energy I September 2022

2

Njonji Oil Field

Shell

A final investment decision has been made to build the 200MW electrolyser which will produce 50,000 – 60,000kg of hydrogen per day. The electricity will come from the Hollandse Kust (Nord) wind farm. Construction will begin for the plant to be operational in 2025.

Energy projects and business intelligence in the energy sector The EIC delivers high-value market intelligence through its online energy project database, and via a global network of staff to provide qualified regional insight. Along with practical assistance and facilitation services, the EIC’s access to information keeps members one step ahead of the competition in a demanding global marketplace.

4

Harbour Energy

Harbour Energy announced that the company has completed the drilling of Timpan-1 exploration well, located 150km off shore Indonesia in the Andaman II PSC. The company stated that the well was drilled to a total depth of 4,211m and flowed 27MMcf/d of gas and 1,884bpd of associated 58 degrees API condensate. It is mentioned that further work will be required to establish commerciality and the full potential of the project.

The EIC is the leading Trade Association providing dedicated services to help members understand, identify and pursue business opportunities globally.

It is renowned for excellence in the provision of services that unlock opportunities for its members, helping the supply chain to win business across the globe.

The EIC provides one of the most comprehensive sources of energy projects and business intelligence in the energy sector today.

WORLD PROJECTS USA

INDIA

5

Sparta Offshore Oil Field Shell

$5.5 billion

9

7

BELGIUM / NORWAY

Laminaria-Corralina Fields Decommissioning

North-Western Europe Carbon Capture Infrastructure Project

$260 million

$6.5 billion ACME is planning to develop a 1.5GW green hydrogen and ammonia plant, powered by a 5GW solar plant to produce 1.1 million tonnes of ammonia. The project will cost USD6.55 billion. Ammonia and hydrogen from the plant will be used to decarbonise fertiliser production, for refining and steel manufacturing and for power. pipeline to an onshore central processing facility.

ALGERIA

AUSTRALIA

Northern Territory Government

ACME Solar

Pending approval by relevant authorities and customary conditions Shell announced that they are to acquire the 51% operating interesting from Equinor for the North Platte field, which has been renamed Sparta. The companies will review the FEED work and the development plan.

It is understood that the project could use the same design as previously used for Shell’s Vito and Whale development projects.

BRAZIL

6

Tamil Nadu Green Hydrogen & amp; Ammonia Plant

10

The federal government has awarded Wood with a contract for the decommissioning project. Under the contract, Wood will be overseeing the first decommissioning phase of the Northern Endeavour floating production, storage and offloading vessel. The company will work closely with the Department of Industry, Science, Energy & amp; Resources (DISER) and contractors to ensure the safe, efficient and responsible initial phase of this critical decommissioning scope.

ANGOLA

11

Block BM-C-33 - Pão de Açucar Gas Field

Hassi R’Mel Gas Field – Lias Carbonate Reservoir

Block 17: CLOV Field Development Phase III

$4 billion

$1 billion

$850 million

Equinor

TechnipFMC has signed a letter of intent with Equinor for an integrated front end engineering and design (iFEED) contract for the project. The FEED is expected to lead to an EPCI contract worth more than US $1 billion following a final investment decision, which could be seen in May 2023. Pending the FID, the EPCI contract would include subsea trees, manifolds, jumpers, rigid risers and flowlines, umbilicals, PLETs, subsea distribution units and topside control equipment, in addition to life-of-field services that will become operational

by Q2 2023.

Sonatrach

A significant new gas discovery made by Sonatrach in the Sahara Desert may contain up to 12 trillion cubic feet of reserves. The preliminary evaluation of this potential showed a volume that varies between 3.1 Tcf and 13 Tcf of gas. The project intends to move quickly, with the first production beginning in November 2022. A development work program is underway to confirm the estimated volumes and achieve fast-track production of around 300 MMcf/d.

Total

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8

Equinor / Fluxys

$1 billion

Equinor and Fluxys plan to develop an infrastructure project connecting Belgium to Norway to capture carbon dioxide (CO2) from emitters to store in the North Sea. The project includes a 1000km CO2 export trunkline operated by Equinor which will transport CO2 for storage under the seabed on the Norwegian continental shelf. A final investment decision is expected by 2025.per annum of green hydrogen and 10 million tonnes of green ammonia.

USA

12

Corpus Christi LNG Liquefaction Terminal Stage 3 Cheniere Energy

TotalEnergies and its partners have reached a final investment decision (FID) on the USD$850 million CLOV Phase 3 development. This work will see an extension of the subsea production network and its interconnection to the CLOV FPSO to develop additional production from existing fields. It will involve the drilling of five new wells, in water depths between 1,100 and 1,400 metres. The phase is expected to begin production in 2024, with a target production of 30,000 boe/d.

WORLD PROJECTS SPONSORED BY

$10 billion

The final investment decision (FID) on developing the project has been made by Cheniere Energy and contractor Bechtel has been given a full notice to proceed with the initiative’s construction. Startup is expected in late 2025, most likely in Q4.

22

DIGITAL TRANSFORMATION

Digital Transformation in the Energy Industry

(Credit: Shell)

The energy industry is in the grips of the most disruptive events since the oil crisis of the 1970s, with energy crises and skyrocketing energy prices in every corner of the world since the Russian invasion of Ukraine.

Global energy commodity flows have been upended, supply chain issues and cost inflation pressure oil and gas producers and renewable energy developers, and volatility on the energy markets is at a multi-year high.

In these uncertain times of high geopolitical tensions and a war in Europe for the first time since World War II, energy firms look to embed and implement more digital solutions to protect themselves against cyber threats and disruptions. High oil and gas prices are beneficial for E&P companies who have recently announced record profits for the second quarter of this year.

Yet, all companies have seen time and again the effect of volatile prices on their bottom lines and aim to be prepared for

www.ogv.energy I September 2022

the next downturn with improved efficiencies and operation flows and minimized costs.

Increased digitalisation could help firms tackle today’s market challenges and adapt better to the next crisis in this cyclical industry.

“Digital transformation is occurring on a massive scale due to the need for increased efficiency, safety and sustainability,” Frost & Sullivan said in a recent analysis of the global oil and gas automation market.

Energy firms, including the oil and gas sector, utilities, and renewable energy developers and providers, use digital solutions to continuously improve safety, streamline operations, cut costs, innovate, or bolster cyber defences.

Data analytics, machine learning, predictive analysis, robotics, automation, digital twins, subsea simulations, augmented reality (AR), and virtual reality (VR) are all being adopted by the leaders in the digitalisation for leaner costs and smoother operations.

“New disruptive technologies, including artificial intelligence (AI) and the Internet of Things (IoT), are already in use and driving digital trends across the industry,” Frost & Sullivan said.

Oil & Gas Set To Invest More in Technology The oil and gas sector is increasingly investing in digital transformation to support safety, increase efficiency, boost sustainability, and improve emission detection and measurement as major companies aim to become net-zero energy firms by 2050 and drastically cut emissions from operations as early as in 2030.

New technologies are expected to play a bigger role in oil and gas as the industry recovers from the pandemic.

The automation market in the oil and gas sector is expected to reach revenues of $24.63 billion by 2025, up from $17.17 billion in 2020 and growing at a compound annual growth rate of 7.5%, Frost & Sullivan reckons.

“Operational technologies (OT), such as supervisory control and data acquisition (SCADA) systems, distributed control systems (DCSs), and programmable logic controllers (PLCs), are already in place,” said Agustina DeSarriera, Research Analyst, Energy & Environment at Frost & Sullivan.

DIGITAL TRANSFORMATION “However, to optimize automation, companies will soon have to include artificial intelligence, Internet of Things and robotics technologies in their operations,” DeSarriera added.

In addition, environmental regulations are compelling the industry to become more sustainable, and participants are recognizing that one of the easiest ways to achieve higher process efficiencies is automation, Frost & Sullivan’s research analyst noted.

Digitalization Becoming Crucial for Energy Industry Digitalization is becoming increasingly crucial for the oil and gas sector as it enables the industry to improve productivity and profitability by streamlining operations, GlobalData Plc said in a report earlier this year.

“The adoption of digital technologies in oil and gas was initially sporadic, with a focus on select critical equipment and workflows. The shortage of skilled technicians, concerns over data security, and cost-benefit uncertainty for adapting aging assets have hindered the adoption of digital technologies,” GlobalData said.

“However, this is starting to change, as companies upgrade their assets with digital technologies for long-term gains.”

During the COVID lockdowns, the use of cloud computing and cybersecurity received a boost as remote working practices increased, the data and analytics provider notes.

Digitalisation efforts in the midstream sector are also expected to receive a boost this decade especially with the LNG boom driven by buyers looking for non-Russian gas supplies, according to GlobalData.

Technology intelligence firm ABI Research estimated in a report in December 2021 that by the end of this decade alone, oil and gas firms globally are set to spend as much as $15.6 billion on digital technologies, as they look to overcome commercial, operational, and existential challenges.

pollution from gas flares. Increasingly, however, network security is rapidly becoming a concern for both the C-suite and Governments,” said Michael Larner, Industrial & Manufacturing Principal Analyst at ABI Research.

Spending on security services is expected to rise by a compound annual growth rate (CAGR) of 8.1% from 2021 to 2030 and reach an annual spend of $640 million at the end of the decade, ABI Research’s analysis has found. Expenditure on by oil and gas companies on Internet of Things (IoT) devices and application platforms is forecast to top $5 billion in 2030 with data analytics spend approaching $2 billion, the technology intelligence firm reckons.

“The role of technology is evolving from helping Oil and Gas firms monitor their large, complex, and dangerous operations to helping them optimize their facilities to handle the volatility in their operating environments,” ABI Research’s Larner says.

said Dominique Bonte, Vice President, End Markets at ABI Research.

“The technologies can enhance decarbonization through more efficient energy use, better project planning, predictive maintenance, greener mobility options (such as e-bikes and e-scooters), and greater urban management through better data management,” Bonte added.

Then there is the electricity sector, which also faces challenges in grid upgrades, smart metering, and stable performance amid growing shares of renewable energy sources.

The adoption of Advanced Metering Infrastructure (AMI) is set for exponential growth this decade, which prompts Its important for utilities and energy organisations to suppliers to revisit their digital security agendas ensure that they are and device management gaining proper value operations, an ABI Research report showed from the collection in May.

of data

Apart from applications in oil and gas, digital twins, IoT, and AI are expected to be the critical enablers in the journey to Net Zero in cities, ABI Research said in July.

While digitization of traditional electricity grids and the modernization of the aging energy infrastructure is among the top concerns for operators and governments worldwide, security for last-mile energy consumption applications was frequently overlooked in the past. That’s no longer the case, according to ABI Research.

“The principles behind smart city technologies, such as increasing efficiency, better data management, and better decision making are also essential for decarbonization and reaching net-zero goals. Technologies such as digital twins, smart streetlights, micro-grids, computer vision, smart city management platforms, and micro-mobility are all growing in popularity and can help with decarbonization,”

“The introduction of AMI, smart metering, and grid digitization is steadily increasing spending for secure management services, assisting implementers to transition to IT (information technologies) and OT (operational technologies) security services and help tackle their primary objectives,” said Dimitrios Pavlakis, Senior IoT Cybersecurity Analyst at ABI Research.

Digitalisation Could Be Enabler of Net-Zero Cities

Technology and digital transformation could help oil and gas companies analyse the condition of their assets, support action plans to expand low-carbon operations and renewable energy production, and prepare for the inevitable volatility of energy commodity prices, ABI Research notes.

Safety of operations and securing assets against cyber threats are key priorities for the energy sector, which is also seeking to proactively prepare for the energy transition.

“Safety and Security are top priorities for Oil & Gas operators. Data analytics allied with IoT platforms have become essential to identifying issues ahead of time such as pipeline degradation, wellhead performance, and

(Credit: Shell)

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DIGITAL TRANSFORMATION

WISDOM IN THE DIGITAL AGE In the 1934 poem ‘Choruses’ T.S. Eliot wrote “Where is the wisdom we have lost in knowledge? Where is the knowledge we have lost in information?”

Almost 90 years’ later most organisations face the same challenges described by the poet to some extent.

Energy operators and contractors in the North Sea have spent the last 40 years collecting mountains of data. This data might take a variety of different forms and be used by different parts of the business. Such examples include data on asset locations, equipment installations, inspection data or condition reports, data on repairs or replacements, work scheduling data, or personnel onboard data, to name but a few. The list of data types held by every organisation is endless and in the digital age it is growing rapidly with every passing day.

The conundrum is what do we do with it? How do we leverage all of the independent data collection activities that are happening in multiple places and for varied reasons or departments? What do we do to ensure that we can all gain valuable information from this data and can successfully turn that information into organisational knowledge and ultimately ensure we retain that wisdom for future successes?

Historically, whilst we all find ourselves with a lot of information the value gained from transforming the information into knowledge is difficult. Often lots of disparate information from multiple data sources creates a very difficult environment for successful knowledge transformation. Organisations may have lots of ‘noisy’ or meaningless data alongside the useful data captured, which can make it increasingly difficult to gain value as often the meaningful information is lost in a sea of noise.

At CAN Group, we are passionate about may determine that an anomaly or defect is ensuring efficiency, and overall value earned present on the site, this will often merit a repair from the transformation of data. Over the or replacement of the equipment in question. last few years, CAN Group has invested over We can leverage value by visualising this on a £1million in its data intelligence platform 3D walkthrough of the asset where these repairs ENGAGE, the premise of which is simple or replacements are going to take place. This we want to ensure our customers can utilise can ensure that any additional risks in terms their data, whether that be historical/as of location can be accounted for as well as built specifications and drawings, enabling better planning. The digital twin current photographs, or even last could show that there are several week’s Ultrasonic test data. anomalies in close proximity to ENGAGE’s user dashboards each other or forming part of the Its important for allow this information same module, this can better aid organisations to to be presented in an the planning process and ensure easy to digest format, that as many tasks as possible ensure that they are facilitating real-time critical can be completed at the same gaining proper value decision making based on time. For an offshore platform knowledge gained. or FPSO this ultimately ensures from the collection In recent times CAN Group that work can be completed in of data has taken this premise a the fewest possible trips which step further with integration vastly reduces risk to personnel between ENGAGE and a leading from any threats posed by the defects, provider of digital twin technology. as well as realising value to the operator in terms of reduced labour cost; win-win all round.

The advantages of this are clear, by combining the data visualisation afforded It is a clear fact that the future of the North Sea by such technology alongside the data lies in the data. As T.S Eliot wrote all those years intelligence capabilities of ENGAGE we can ago, ensuring that we do not lose knowledge ensure that true value can be achieved from trapped in our information is pivotal to gain the the data gathered. For example, using data wisdom to remain successful for years to come. captured from an on-site team, ENGAGE

Its important for organisations to ensure that they are gaining proper value from the collection of data and completing this full transformation into knowledge and wisdom.

Whilst we are all very good at collecting data, there is little point in collecting Petabytes of data and storing it for all eternity, if it cannot ultimately be easily presented in a way that is valuable to decision makers and stakeholders.

www.ogv.energy I September 2022

CAN GROUP is a market leader in life of asset integrity services with our business streams CAN, ENGTEQ and VENTEQ providing a comprehensive and integrated asset integrity service to deliver innovative solutions to the energy industry worldwide.

For more information visit www.cangroup.net

DIGITAL TRANSFORMATION Stena Carron

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Care Tablet

DATA-DRIVEN PERFORMANCE ‘What gets measured, gets managed’

At the heart of any Digital Transformation is a data strategy that sets the foundations required to leverage the value of digital commodities. At Stena Drilling, we don’t view data strategy and digital transformation as separate, we see a connected, datadriven technology landscape that sets the scene for organisations to get the most value out of their digital technologies.

Digital transformation has improved customer experiences, employee productivity, and streamlined many processes, however, many companies fall into the trap of running cutting edge Artificial Intelligence projects without first understanding and structuring their own data landscape. After all, for a machine to learn it requires data. The better quality the data is, the better the machine will learn.

Stena Drilling's Operational Performance Using Digital Technology Over the last two years, Stena Drilling undertook a significant project to overhaul the collection of drilling-related performance data. We deployed a new operational reporting software along with a performance monitoring system using rig sensor data to compute “rig state” which can be used to calculate accurate and quantifiable performance KPIs. This has proved to be a massive benefit to the drill crew on shift by auto-creating the time-event log the driller normally manually maintains for reporting purposes.

By deploying this software across each unit, we are able to compare drilling performance accurately across our fleet. We learn and improve our procedures where a consistent approach is key.

Stena Drilling currently operate 2 out of 6 drillships in Guyana, all operating for the same client, and where a healthy competition takes place between the rigs. By accessing our performance data, we’ve been able to measure and better manage our operations.

Our teams onboard Stena DrillMAX & Stena Carron are already harnessing these new capabilities and have made considerable improvements on operational drilling performance. This has been demonstrated

by Stena DrillMAX winning ‘Rig of the Month’ 3 times this year so far, with Stena Carron winning for July. The winning rig holds the coveted oilfield hard-hat trophy!

Because of the hazardous environment of offshore drilling, we don’t incentivise speed, it is not a race; but we aim for optimised efficiency in the safest manner. By being able to compare how one crew performs against another, we can work out how and why differences can occur. This is not used to penalise, but to develop a consistent approach from each of our crews. Then we can apply the same logic across different Stena Drilling vessels – sharing knowledge and best practices.

We’ve recently formed a dedicated Drilling Performance Team, which includes Toolpushers with extensive offshore knowledge and experience, combined with onshore engineers with rig operational knowledge and data analysis skills. With the complementary strengths of these individuals, and the technology to support them, we can manage performance on a micro-level. The team work closely with each vessel to measure, manage and strengthen performance.

We collaborate with our clients to continuously improve performance, but not just in terms of drilling operations. We’re looking into many new areas from emissions to equipment reliability to open-data sharing plus many more. It is a mutually beneficial arrangement as we share many fundamental goals and objectives. One of the main enablers is data!

We’ve never challenged ourselves to the degree we do now and having access to data is the key to unlocking the insights we’ve never had previously.

With ever-increasing communications speeds, and ever-improving technologies’, we receive more data from offshore than ever before. The onshore team at Stena Drilling have always supported the offshore teams on all our vessels; but now walking through any Stena Drilling office you will see screens with live, operational data on display.

DrillMax Aerial

Oilfield hard-hat trophy

Stena Drilling Improving Safety Performance through Digital Technology Safety performance is always our top priority; we are always looking to contribute to our safety culture. We developed our own in-house behavioural-based safety system: Care (Continuously Assessing Risk Everyday) Observations. A dynamic web-application, accessible from any PC/tablet/smartphone on our vessels and on strategically located tablets onboard, where our employees participate in the Observations system. STOP processes have been around for many years; the difference with our Care system is the technology in the backend.

Through artificial intelligence we automatically assess and categorise observations as they come in; saving hours for our offshore supervisors who previously had to manually read, assess, and categorise. We analyse all data entered and using machine learning, the system itself can determine a new category relevant to the data being entered. This provides us with new insights to understand and improve our policies and procedures; something we would never have been able to do without the use of this technology.

Smart Chain Services (SCS) Alongside our technology partner Smart Chain Services Ltd. (SCS), we have developed a smart contracting solution that enables new commercial models that can be of benefit to parties by delivering a level of data auditability, trust, transparency & security that is not available in any non-blockchain technology.

For example, with a delivery-based contract, rather than traditional day-rate based, rig teams are incentivised to complete the operation as efficiently and safely as possible, but all parties can share in the success of a successfully delivered operation.

Digital Technologies have been a true enabler, the way we work has changed, the workplace has changed and how we learn and interact with data has changed. Through this improved operational performance, we are delivering client value and are evolving to become a digital leader in offshore well construction and decommissioning.

At Stena Drilling Innovation is in our DNA, it's at the heart of everything we do and our approach to Digital Transformation is simply another example of our journey to deliver safe and efficient value to our clients.

For more information see our website: www.stena-drilling.com

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DIGITAL TRANSFORMATION

INDUSTRYFOCUSED DIGITAL ENABLEMENT In an evolving industry and diversifying market, introducing technology and software to reshape processes and operating landscapes can reap significant benefits.

Increased organisational efficiency, improved safety performance and increased predictability in operations are key metrics we continuously improve together with our customers.

Digital enablement must be embraced in a competitive industry where improvements in employee safety, productivity, and sustainability are at the forefront of a value driven ethos.

Celebrating 10 years in the business Established in 2012, founders Robert Noble and Mike Rudd, engineering experts in flange management, looked to empower the industry by offering software that reduced time, costs and increased safety in bolt load assurance. The founders of asset55 understood the impacts of time-consuming, outdated manual methods used in flange management and how digitalisation of this process would benefit operators in the industry. From this journey of industry experts and software developers working in harmony, our company was born.

In the following ten years, asset55 has seen exponential growth, now offering four cloudbased software solutions across the capital project and operational space. Calculate and Operate for operational assets and Validate and Execute for capital projects.

Asset55 are trusted software providers to the most respected names in the global energy sector. The digital enablement of our software promotes an environment for safety and productivity to prosper through our core principles of data integrity, optimal planning, and control in execution.

Standing out in a crowd Designed by industry for industry. Who better to design a software process than subject matter experts from the operational and

www.ogv.energy I September 2022

capital project space. Our technical team can speak to the challenges faced in industry and support our clients with a hands-on approach to mitigate and continuously improve overall organisational performance.

By leveraging technology and industry expertise, we provide valuable insights into challenges and opportunities for our customers by enhancing existing company processes. Our technical team works together with our end users to collaborate, innovate,

and continuously improve performance outcomes through mitigation methodologies and capitalising on the opportunities that exist within established process.

Asset55 implements a 1:1 ratio of Engineers and Software Developers, combining industry expertise with technical assurance. Our in-house technical authorities, operations leaders, and project leaders contribute to maintaining robust industry requirements by working together with our industry bodies.

”It is a privilege combining hands on industry experience together with innovate technology developers to solve real challenges in the operational and capital project space.”

Conor O'Leary – asset55 Director

Time for a refresh

Calculate (previously iQ)

This year, following our ten-year anniversary, asset55 decided it was time for a brand refresh. Software is forever evolving, and it was important that the brand represented this growth and change. In the industry itself a catalyst for change can be found through the increasing diversification of the market. With the growing energy evolution and shift of focus to renewables and carbon capture, one must adapt or risk falling behind. These were all catalytic determinants in how asset55 would handle our rebrand strategy.

Bolt load calculations derived from legacy systems, spreadsheets or even slide-rules has led to outdated and often inaccurate tightening practices, which can cause damage to components, increased costs, and risk of downtime. The assurance in safety of these methods also must be brought into question – with incorrect bolt loads leading to a potential hydrocarbon leakage.

The first step was the brand logo itself. The addition of a logo was a decision made in becoming not only a visual identifier for potential clients in the industry but a visual indicator of what the brand has to offer. The logo takes the form of four petals in differing colours, representing the four-software provided by asset55 – Validate (purple), Execute (yellow), Calculate (blue), and Operate (green).

Our Calculate software is designed for bolted joint integrity and flange management assurance. The secure cloudbased platform and integrated modular build supports the whole range of workflows. From carrying out individual bolted joint calculations to full flange management process and assurance, the software is consistent with the very latest industry best practice guidelines.

Next came the change in naming convention of the software. We all know this can be a potential risk for any company, the renaming of products can pose a threat to existing product recognition. However, with the vast intellect of the software at asset55, a rebrand in product name was a necessary step in capturing more precisely the capability of the software.

The unique built-in joint integrity review feature allows an assessment of any given bolt load across an almost infinite variety of flange assembly combinations. This allows the user to make informed decisions to reduce potential schedule slippage, hydrocarbon leakage, and the hidden cost of component damage.

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Execute (previously Construction Solutions) In a challenging, remote, and fast paced environment, Execute was designed to ensure smooth workflow execution. Underpinned by technical consultancy and governance enabling optimized 4D preparation, Execute can provide greater visibility and control over capital project outcomes and enhance the communication of plans and critical priorities for all project stakeholders.

Full digitalisation of a capital project directly improves schedule, budget, performance, and organisational efficiency.

In fact, Execute has seen cost savings in the range of $20 million to $150 million USD and production revenue of over $300 million USD due to earlier start up and decrease in schedule. Cost savings is not the only benefit realised with the utilisation of digital software, safety incidents can be decreased by up to 80%, cable pulling productivity increased by up to 250%, hydro testing and leak testing optimisation can improve schedules by up to 200%, and project reporting time reduced by up to 150% due to trust automated reporting.

Operate (previously iQ control)

Validate

Operate is a cloud-based solution for optimal preparation, planning and execution of time critical tasks. We leverage data and technology to secure data integrity, optimal planning & preparation, and robust scope management in the operational space.

Trusted data is vital to secure a successful outcome in project performance and asset performance in operation. The manual process of validating data requires time and resource; however, precision and consistency are not guaranteed. Poor data quality and the resulting resource and time constraints have a direct impact on project schedule, budget, and organisational capacity.

Through digital enablement of operation processes, the multidiscipline execution platform was designed to deliver planned maintenance, operational assurance, modifications, and TAR scopes.

In collaboration with industry operational leaders and innovative software developers, Operate was designed to provide the effective real-time collaboration needed between onsite and support teams in the most remote locations. It is important to provide agility within an operating environment, enabling teams to work more effectively with better allocation of resources - promoting the industry drive to develop a multi-skilled, digitally enabled workforce.

Validate is our automated data validation software that addresses this major industry challenge of poor data quality. Through automated validation of data sources, we provide real-time, line of sight into engineering maturity and identify data inconsistencies before they impact project performance.

Validate has the ability to analyze thousands of tags and millions of attributed data points versus conformance, consistency, and completeness of the asset’s data foundation. It currently completes over 15,000,000 validated data points checks monthly across multiple capital projects.

assetfiftyfive.com Aligned across two divisions, Operations & Projects, we enable change through a portfolio ​of execution specific software, which share two common traits – Improving safety and improving productivity to our clients.

Learn more at assetfiftyfive.com

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king and Maintaining Making and Maintaining e Right Connection the Right Connection c Engineering has specialised in the

acture of high pressure Flanges, Seals Destec specialised in the nections forEngineering the Oil, Gashas & Renewable manufacture of high pressure Flanges, Seals y Industries for over 50 years. & Connections for the Oil, Gas & Renewable Energy Industries for over 50 years.

PRODUCTS WE DELIVER: -

www.ogv.energy I

SERVICES WE OFFER: - On-Site Machining PRODUCTS WE DELIVER: SERVICES WE OFFER: - Bolt Tensioning DESALIGN Misalignment Flange - On-Line Leak Sealing G-Range 4 bolt connectors On-Site Machining - Overlay Welding Compatable seals Misalignment Flang e - DESALIGN - Bolt Tensioning GSB subsea single bolt clamps - G-Range 4 bolt connectors - NDT Services - Overlay Welding Compatible seals - Compatable seals - GSB subsea single bolt clamps - NDT Services

T +44 (0) 1522 791 721 | F +44 (0) 1522 790 033 sales@destec.co.uk | www.destec.co.uk T +44 (0) 1522 791 721 | F +44 (0) 1522 790 033 sales@destec.co.uk | www.destec.co.uk September 2022

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Historically if you required applications or software built you needed to rely upon Professional Developers. This is all changing as modern software platforms permit Citizen Developers to build advanced software systems and applications without the reliance on Professional Developers.

These new software platforms are delivering a 10x improvement over the traditional software development approach.

INTERVIEW WITH STEVE HIGGON

Citizen Development is a Key Enabler of Digital Transformation

OGV Energy interview Steve Higgon, CEO and Founder of TAAP. www.ontaap.com

Do you have a strategy to on-board Citizen developers?

Gartner predict in 2023 that there will be 4x the number of Citizen Developers as Professional Developers.

What is a Citizen Developer?

A 2020 Gartner survey shows that 41% of employees outside of an IT role fit a description called business technologists — those who customize or build applications, automations and technology solutions for work. Citizen development is the practice of enabling a community of likeminded business technologists using shared No Code and Low Code tools to create automations and apps in a safe and scalable way.

Database Designers, BI Analysts, Front End and Back End developers, the testers and the DevOps teams standing up the final application prior to production.

Business units increasingly control their own application development efforts, of which Citizen Developers are playing a crucial role. Application and software engineering leaders must help define and guide citizen development to maximize mutual benefits for business and IT.

Traditional software development using Professional Developers has a significant cost and time impact compared to the latest Superapps and No Code Low Code Platforms.

The Citizen Developer is often a domain expert and understands the data they want to capture, process, transform and report against.

By allowing Citizen Developers to create the apps they need with advanced software platforms, it dramatically reduces the cost and timescales required to have Professional Developers support these end users, creating the applications that they need.

This however isn’t the end of the Professional Developer. Citizen Developers are able to be self-sufficient whilst supported by Professional Developers and IT teams. Professional Developers can focus on the more complex challenges and processes, further enabling the Citizen Developers to be able to do more faster, and together providing a better overall service to the business operations of the organisation.

Professional Developers normally work within a team of people that exist to create the apps that are required for the end users to utilise.

There is usually some formal specification created that requires a detailed description of the process required, cross training the Professional Developer, helping them to understand the needs of the end user, the domain expert. This is often where projects fail, the clarity around the requirements, the miscommunication between the end user, the Project Manager, Business Analysts,

TAAP provides a No Code Platform to help Professional and Citizen Developers to work together more effectively, working as Fusion Teams. These are small targeted focused and efficient groups of individuals with complementary skills that together are helping organisations of every size become agile enterprises.

Citizen Developers are a new resource you need to plan to embrace into your organisation for 2023.

If you don’t have a digital transformation platform then you don’t have a digital transformation strategy.

Contact TAAP to bring to life your next digital transformation project.

Learn more at www.ontaap.com

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DIGITAL TRANSFORMATION

USING INNOVATIVE DIGITALISATION SOLUTIONS TO VISUALISE YOUR ASSET

Digital Twin is fast becoming a popular term in the oil and gas industry as we look for digital transformation strategies to support the Energy Transition.

What is a Digital Twin?

A Digital Twin is a digital model, or virtual representation, of a physical object or structure.

Think of being able to view the Mona Lisa through a virtual tour or being able to view a pipeline on your energy plant, from your desk, whether onsite or at home.

A Digital Twin brings the ability to view a physical object or structure remotely. In the Energy industry, this could be a piece of equipment in a Refinery, or it could be an entire Offshore Oil Platform from topsides to subsea.

When we introduce Geospatial data (and other types of data) to a Digital Twin, the use cases soar far beyond remote viewing or ‘virtual tours’. It accelerates you towards a complete digitalisation solution to visualise your energy asset.

What is the difference between a Digital Twin and a Geospatial Digital Twin?

A geospatial digital twin is a digital model of a physical object or structure that includes data relating to its location. It depicts the structure in relation to its surroundings to provide better context.

What is the distance between the pumps and the pipeline? What is the height of the office building in relation to the nearest structure? Will this new kit fit in the existing space? These are all answers that the Geospatial part of a Digital Twin can provide.

In addition to looking at a piece of equipment or structure remotely, you’re seeing its precise location in the world, with the ability to measure space and ‘layer in’ much more visual data.

www.ogv.energy I September 2022

How is a Geospatial Digital Twin created?

and is enhanced through integration of other digital data sources, such as asset registers or live data feeds from equipment.

A Digital Twin first requires a digital replica, from which it can then expand. The digital replica is typically created through reality capture processes such as 360 Photography, Photogrammetry, LiDAR/Laser Scanning, 3D Mapping such as Simultaneous Localisation and Mapping (SLAM) or an existing 3D Model.

With an array of features and functionality including tools for measuring, drawing, tagging, management of change, uploading documents, viewing comparisons and integration with live data, ZynQ transforms the replica of your asset into a comprehensive geospatial digital twin that supports sustainability, and improves profitability through digital transformation.

Whether it’s a digital replica as if you were looking at it with your own eyes (360 Photography/Photogrammetry), or as a Point Cloud (Laser Scanning/LiDAR/SLAM), there are multiple options for how to create a digital replica of your asset, each offering different levels of quality and accuracy. Once the reality capture has been completed, you have an ‘asbuilt’ digital replica of your entire asset, from the smallest valve to the largest structure.

Empowering Entire Workforces

What you do with the replica is how you harness the true value for safer, sustainable, and more cost-effective operations.

Geospatial Digital Twins will empower entire workforces to work smarter through enhanced communication and maximised collaboration, providing operational excellence across use cases such as: Turnarounds, Maintenance and Decommissioning Planning, Inspection, Asset Integrity, Remote Engineering, Management of Change, Asset Familiarisation, Emergency Response, Risk Management and Immersive Training.

As an industry-agnostic software solution that integrates new and existing visual data, use cases span across an array of assets, projects, or sites.

What can you do with the Visual Model?

After a high-quality replica of your asset is generated, it’s time to put this to work via a platform that can plot it geospatially and integrate it with your existing data.

ZynQ 360 – Supporting Digital Transformation through Visualisation

ZynQ 360 offer a secure, cloud-based visualisation software platform called ZynQ. The team of visualisation experts at ZynQ 360 create holistic, digital replicas of assets, then geospatially plot, build, and deliver those within the ZynQ platform, enabling entire workforces to view and interact with them from anywhere at any time.

ZynQ’s intuitive user interface is designed to get the most from the digital replica of your asset

Our ZynQ software platform is at the core of how we deliver real value. It is sustainable, adaptable, affordable and accessible across entire organisations.

With 30 years of knowledge, industry insight and expertise in providing innovative digital solutions to the energy industry, ZynQ 360 are a partner you can trust to deliver you a Geospatial Digital Twin that will reduce costs, risk, and your carbon footprint - from day one.

Scan to watch our ZynQ Software Video

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NEVER STOP LEARNING – WHY ENERGY SECTOR TRAINING IS EASIER WITH DIGITAL Despite its commitment to continuous training, the energy industry has often struggled to offer its teams longerterm skills development opportunities.

With the need for operational and regulatory requirements to take priority, companies have tended to focus their attention on closing immediate capability gaps - usually with short term training that can add up to little more than a tick-box exercise.

Now, e-learning is providing a more effective and sustainable solution, delivering a full suite of upstream training courses spanning the entire project lifecycle. Users learn faster and remember more, while managers gain granular insights enabling them to create highly tailored programmes to optimise performance and support their teams.

Better for learners A career in the energy sector has always involved an element of uncertainty. Oil prices and activity levels fluctuate, businesses are forced to adapt and today we can see a global energy transition rapidly changing the expectations and skillsets of the workforce.

By developing transferable knowledge and skills that may be applied to future renewables, carbon capture or decommissioning projects, and deepening understanding with more complex courses, learners can advance their learning in a manner that is mutually beneficial with their employer.

When it comes to the where and when of learning, individual learning preferences will always vary – that’s why a flexible model is needed to provide the maximum growth opportunity for every learner. Retention rates of classroom-based training are as low as 8-10%, while digital training methods increase retention by up to 60% (1).

As well as providing training that allows learning at the optimal time and place, it is also important that training reflects how learners want to learn. Watching online videos is now the preferred method of learning among those aged 16-54 in the UK (2) – and effective digital training platforms will feature a range of media including video to reinforce learning and engage users.

Better for employers The granular insights into individual development that digital training platforms provide has created a new level of planning capability for training.

Combining these capabilities with easy-touse interfaces, employers can now build fully customised courses built around team-wide and individual competency gaps while having constant access to training progress and assessment performance data.

These capabilities allow for a smart approach to both the planning and measurement of effective training programmes – not least by vastly improving efficiency.

Learners perform best when courses are made up of smaller, bite-sized pieces of content – in contrast, operational pressures mean that classroom-based training usually requires as much material as possible to be squeezed into sessions. Because digital training gives learners the flexibility to squeeze in smaller chunks while also naturally reinforcing information through feedback, the time to absorb information is significantly less than traditional courses. In fact, real hands-on training time is 30-50% less which makes for a huge financial and time saving for operators (3).

Want to learn more?

Norwell EDGE is the digital training platform for the oil and gas industry. For a simple and flexible implementation, our modules can even be integrated with operators’ own internal training systems. Request a demo today – or why not get in touch to request a free trial for your teams?

Offering learners a platform to take control of their own learning has huge benefits for both the individual and the employer.

Accessible 24 hours a day from any device, learners can manage their training around operational imperatives, while the latest digital training techniques provide bite-sized, blended learning meaning a shorter, more frequent study period – allowing greater flexibility.

Some specialist e-learning companies like Norwell EDGE have developed technology that enables the learner rather than the employer to own their training portfolio. This ensures that an auditable record, certified learning and access to a wealth of reference materials stays with them as they move throughout their career – even when they move to a new employer.

Norwell EDGE is built around the Oil & Gas UK’s wells competency guidelines. Our comprehensive range of modules can be combined to create a programme to meets the competency needs of your people For more information visit www.norwelledge.com

32

INNOVATION & TECHNOLOGY ZONE

SPONSORED BY

The UK’s largest innovation funding consultancy Our expert teams work in close partnership with thousands of businesses each year to maximise the financial benefit they receive from R&D Tax Credits, Grants, and other innovation funding schemes.

www.leyton.com

In the past year alone, we have helped our clients successfully claim more than £200m in tax relief to support their future growth.

WATCH VIDEO

INDUSTRY SOFTWARE That Solves The Worker’s Problems

About us Aize was founded in 2020 with a vision to fundamentally change how capitalintensive projects and operations are performed. Developed by and for domain experts, the Aize workspace allows users to see, navigate, collaborate and work on assets digitally. The company is building on 30 years of software experience and 180 years of industrial heritage as part of the Norwegian Aker group. Aize is based in Norway and the UK.

Company Details Website: www.aize.io Email: info@aize.io Tel: +44 (0) 7522 729412 Address: Building 2, Aberdeen International Business Park, Dyce Drive, Aberdeen, AB21 0BR, United Kingdom

Technology Development stage: Commercial Launch date: 2020

www.ogv.energy I September 2022

W

e founded Aize in 2020, and already benefit from solid industry collaborations. We root our mission to transform the industry in five decades of world-leading offshore industrial expertise.

With Aize, we are now creating one core product with modules and functionality that will serve heavy-asset industries throughout their life cycle.

For us, the worker is in focus The Aize workspace lets your data collaborate so that your people can collaborate in real-time, eliminating unnecessary paperwork and physical meetings freeing up time for every industry worker to do their actual job.

Our goal: To create industrial software enabling one single source of truth for companies and experts building, operating and collaborating on heavy assets, enabling them to utilise the digital twin in the best way possible.

For workers in EPC Aize lets you coordinate capital-intensive projects together in real-time. Streamline all communication and relevant data involved in designing, constructing, and commissioning heavy assets into a single source of truth.

Aize empowers contractors, vendors and partners to make unified decisions based on the same information. A combination of 3D visualisation, advanced information modelling and Google-like search experience will help you understand data in actual context, driving efficiency and profitability of greenfield developments as a result.

For workers in operations Aize is a collaborative, shared workspace bringing entire heavy assets to its operator’s fingertips. Running an operating facility can be capital-intensive and requires solid control over maintenance and safety. That’s why Aize provides a single access point to all engineering data by integrating internal and 3rd party apps. As a result, operators are always a few clicks away from determining the overall asset performance, enabling them to act quickly and confidently.

3 things you should know about Aize 1. Our job is to keep every industry worker involved in heavy-asset projects or operations in the know and help them excel at their job.

2. Digitalisation is not the goal in itself.

We work to create a simpler, more creative and more productive every-day for industry workers, empowering them to spend less time looking for information and more time on critical tasks. Aize helps build more sustainable and competitive companies, both large and small.

3. We focus on our domain because we genuinely believe the change in the oil and gas industry is essential to changing everything.

Building a more sustainable future will take time. We are doing our part in speeding up the process by starting in the industry we believe is most influential at the moment.

Find out more about Aize at www.aize.io

INNOVATION & TECHNOLOGY ZONE

3D SUBSEA SCANNING – THE DEVIL IS IN THE DETAIL 3D scanning is fast becoming the energy industry’s go-to measurement methodology for subsea and other challenging environments. It is, however, a wise operator or service provider who understands that no single method or equipment spread covers all scenarios.

Viewport3 specialise in the projects that are technically challenging, the ones where there is simply no margin for error. The Aberdeenshirebased firm provides 3D scanning and reverse engineering services - using digital cameras to obtain technical grade point-cloud data, which they process into 3D datasets to produce straightforward reports and geometric outputs.

To date Viewport3 have worked on twenty projects whereby the data they capture provides the customer with an exact 3D copy of the subsea challenge. Why is this accuracy so important? Because it means the customer can design their solution in such a way that it fits first time. Viewport3 have dubbed this ‘wrap-around design’.

Accuracy of data saves 20 days vessel time When a major North Sea marine contractor needed a detailed understanding of the shape of the hull of a semi-submersible asset in order to accurately design cofferdams for the hull, Viewport3 worked with them to deliver just that. The team specified and operated the capture system, before carrying out the 3D reconstruction and engineering analysis.

The challenge Conventional measurement methods couldn’t provide the level of accuracy required inaccurate and imprecise data would add time to the installation process as it would result in more on-site fitting adjustments. Moreover, the traditional methods would take longer to mobilise, and indeed to collect the required data.

The solution Viewport3 designed a project-specific camera and lighting arrangement for the ROV capture platform, which efficiently captured demonstrably high-end digital data – far exceeding the accuracy requirement detailed by the customer at project conception.

The 3D outputs of the hull shapes were delivered to the engineering contractor, allowing them to use the geometry as a basis for the cofferdam and plug designs.

The result Viewport3 supplied the data required at an accuracy level that reassured all parties, with data capture completed in just 8 days, as opposed to the normal 21 days for this type of project.

Overall, Viewport3’s input saved the operator approximately 20 vessel-days between the measurement and install phases, reducing the strain on IRM budgets and minimising schedule disruption.

It is estimated that the cost of replacing the flexible riser would run into the millions of pounds, dwarfing the cost of applying a fit-firsttime retaining clamp, based on real-world 3D geometry extracted by the Viewport3 process.

Deviation analysis detail changes from primitive

Grating captured during hull scanning project

Remote scan of flexible riser saves millions

Complex seatube scanning prompts successful installation campaign

Jonathan Fuller During an ‘as-laid’ inspection of a recently installed flexible riser in the Norwegian North Sea, the operator’s marine contractor found a small section of the riser to be mis-shapen, thought to be caused by the installation equipment.

Prior to modification works on the hull of an FPSO, a North Sea operator identified a need to plug open ‘seatubes’ in order that works could be conducted on the water handling system. With no original CAD or drawings of the item available, the client required a 3D scan of the area.

In collaboration with an international marine contractor, Viewport3 performed a highaccuracy 3D scanning operation aimed at recording the ‘new’ shape of that particular section of riser.

The challenge

The challenge The capture was organised in a ‘remotely managed’ configuration, whereby the imaging equipment was issued to the marine contractor, alongside a guidance procedure and 3D animation.

With no opportunity to excavate around the site of the anomaly, it was crucial that the image set also captured the flexible / seabed interface as accurately as possible.

The solution A virtual meeting ‘walked’ the ROV team through the operation, whilst highlighting best-practice in terms of collecting technically valuable images.

The data was then reconstructed in 3D. As well as standard geometric analysis reporting, Viewport3 also provided 2D ‘slices’ of the riser profile at pre-defined intervals, helping the riser manufacturer to understand the shape and scale of the damage.

The result After completing virtual analysis and effect simulations based on the Viewport3 provided data, the riser manufacturer advised that the hardware was serviceable, and would remain so if the riser could be retained in its new shape and not allowed to ‘relax’ with the passage of time.

Additionally, the near 90-degree bend immediately beyond the seatube opening was not documented, meaning the customer was also unaware of how far into the seatube any plug could be inserted before the bend was reached.

As a result, it was not immediately apparent how an ROV might approach the work site whilst achieving the necessary angles for correct cleaning and image capture.

The capture was planned and executed remotely, whereby the imaging equipment was issued to the marine contractor, alongside a guidance procedure and 3D animation.

The solution A virtual meeting walked the ROV team through the operation, highlighting best-practice in terms of collecting technically valuable 3D geometry.

Changes were also made to the method by which the ROV held and manipulated the cleaning and image capture equipment, so as to address the challenging angle on the bottom of the vessel hull.

The data was then reconstructed in 3D. As well as a standard geometric analysis reporting, Viewport3 also provided angular (pitch and yaw) information, due to the pipework not being perpendicular to the seatube opening.

The result On completion of the 3D reconstruction, the data was subjected to 3D point cloud analysis and reverse engineering to the satisfaction of the customer. The design and manufacture of the temporary plugs proceeded and was followed by a successful installation campaign.

Subsequently, the Viewport3 data was redeployed and used as a basis to manufacture a clamp for the riser, which would hold the item in a manner that matched the nonprimitive geometry at the area of the anomaly.

Viewport3 were glad to hear that the field was subsequently brought into production in Q3 of 2022.

Pitch and Yaw detail from 3D data

33

34

OUR DIGITAL INDUSTRY

SPONSORED BY

Who is Sword?

Paul Newey leads the Digital Solutions team at Sword and Tracy Beglin is a Principal Information Management Consultant. Combined, they bring 46 years’ experience of solving data-driven challenges in the Energy industry. Their teams drive delivery of our MigraPath solution, to leverage the value of organisations’ information and records.

www.sword-group.com

As the North Sea’s largest provider of data and digital services, Sword focuses on solving the industry’s most critical business technology challenges by enabling our clients to capture, manage, and utilise data to make informed decisions. This is supported by technology adoption and people engagement, together with modern ways of working to give confidence that the right decision is made every time.

TRANSFORMING UNSTRUCTURED DATA INTO ACTIONABLE INFORMATION

Paul Newey

Harvesting Value Our third stage centres on classification, tagging and extracting information to harness the business value by increasing information confidence and quality.

We spend time thinking about how to improve processes and align information and data to business processes. Duplicate and outdated information is rife in our industry and the importance of applying a process that delivers data quality cannot be underestimated.

It can become an instant priority if, for example, the critical operations documents are not accessible. The lost production costs if a platform has to shut down while documentation is found would be a daily nightmare until confidence in the right information is gained.

Migration In the final stage of MigraPath, we visualise and transfer information to reduce information management overheads, and increase information accessibility and availability.

Unlimited Data

Data Discovery

There are vast quantities of untapped and unstructured information across the Energy industry, particularly in Oil & Gas where asset transition is common. Often there is inherent value in this data, however unleashing value can be complex, with a lack of clarity on what information is out there, who it belongs to, and what state it is in.

In the discovery phase, we help organisations address their (sometimes ancient) legacy information. Often this information is the primary reason for investment of billions into an asset or acquisition. The information can sit untapped for years as the cost of accessing it has historically been prohibitive.

The monetary value in data, bought in an asset transition or when buying rights to data, can be staggeringly expensive, and one dataset could be paid for multiple times by different departments in one organisation. Within the data, there could be multiple versions and if the wrong version is used, for example as the source for exploration in defining the target for drilling a well, the results could be catastrophic.

With the impact of unreliable data insights so critical to business operations, we help align information and data with business processes so that the right information is available at the right time. We apply an integrated approach to information management, MigraPath, a datadriven methodology, enables enterprise-wide clarity, facilitates rationalisation, reduces time to insight, and supports informed decision making.

www.ogv.energy I September 2022

We help clients to understand their information.

Using a virtual window to demonstrate what their data migration will look like helps our clients to gain business buy-in for sign off on data-driven projects.

Rationalisation Once visualised, we begin a process of identifying and streamlining data. We scour datasets and draw insight from them to help organisations reduce operational risks. This can help avoid hazards, such as with positioning information for boats, where using outdated information could result in a boat in the wrong position and the knock-on effect on operations disastrous.

The goal is reducing time to insight in achieving business benefits quickly and cost effectively, with clear impact on improving operational efficiencies.

We aim to build confidence in our client’s information so they can trust their data and make informed decisions. We also establish a process of governance and compliance that drives down risk, including reputational risk, as if an organisation gets an operational decision wrong then it can result in negative public reaction in addition to financial penalties.

MigraPath in Action We applied MigraPath to tackle a global Oil and Gas operator’s inherited information estate, arisen from various business acquisitions, which was a mix of live and outdated information totalling over 320TB and 25 million+ files. Over 4.8 million duplicate, ROT, Archive and PII files were removed, significantly reducing the time to locate and find the right information. Combined with many other resulting benefits, we enabled informed business decisions that helped our client to make the most of their acquisitions and increase operational efficiencies.

As organisations hone their focus on becoming data-driven, the reliance on quality information being available at the right time for timely decisionmaking is increasing an exponential rate. If the industry is to achieve data-driven outcomes, then we need to make sure that data is placed at the heart of our operational and project thinking.

For more information, visit www.sword-group.com

36

RENEWABLES

SPONSORED BY

Step into a safer environment High quality, industrial anti-slip safety products.

www.scotgrip.com

For over 30 years, we’ve designed and manufactured market-leading anti-slip safety products that hugely improve safety standards on stairways, walkways, decks, ladders, ramps, gangways and pipes, in a range of industrial settings.

THE ROLE OF OIL AND GAS COMPANIES IN OFFSHORE WIND ENERGY PRODUCTION

J. Coleman

Electricity generation from wind power in the UK has increased by 715% from 2009 to 2020. In 2020, the UK generated 75,610 GWh of electricity from both offshore and onshore wind. This level of growth is very encouraging, with renewable energy becoming more and more dominant both in the UK and across the globe. But what does that mean for companies in the oil and gas sector? And, how can oil and gas companies incorporate the use of renewable energy sources into their own businesses?

When mapping potential and existing offshore wind farm sites, we see that oil and gas sites are often nearby. They require similar environments, such as shallower waters with stable sea beds. With recent mapping, there is now more clarity as to where appropriate sites for fixed offshore wind farms are, which is helpful and can help to speed up the process for developers. This used to be determined on an ad hoc basis, which took more time as local governments had to seek approvals and assess locations for each project.

Developments in offshore winds in the UK and globally Fixed offshore wind farms have been proven to be a reliable mechanism for renewable energy generation at various sites around the world. Currently, turbines, like those on a monopile foundation for example, are driven into the sub surface with a limit of about 60m.

www.ogv.energy I September 2022

Technology for monopiles driven into the sea bed in deeper waters is set to be developed, but will bring with it a higher cost. In areas of 50m+, floating wind farms are often indicated.

Most of the North Sea is under 100m in depth, apart from one area along the Norwegian coast which is around 200m deep. This means that in years to come, almost the entire North Sea is likely to be suitable for fixed or floating wind. From an oil and gas perspective it is probably easier and cheaper to install floating wind near an oil and gas platform than a conventional fixed structure especially in the northern North Sea. There are also plans in Denmark to create artificial islands in the North Sea which will essentially be giant floating transformer stations. This will encourage secure grid connection and cut down on the costs of cables by reducing the number of cables required to go to shore. The Danish energy islands will facilitate interconnectivity while reducing costs in the long term, but may take a number of years to come to fruition.

Globally, the focus on wind energy is also developing. Notably, offshore wind maps now expand to include South America, as Brazil currently has 7-8 projects in the planning stages. Developments are expected from Governments in Uruguay and Chile in the next couple of years as well. As well as this, 3-4 years ago, there were no offshore wind projects in Australia, then one was proposed in the Bass Strait and now the Australian government has announced the countries first 6 offshore wind zones.

Developing technology to go greener With the current technology, vast areas of the world aren’t shallow enough for fixed wind farms. Both the entire west coast of the US and the Mediterranean are mostly deep water, as well as the Atlantic coast of Spain and Portugal.

These are areas where floating wind farms are likely to be best suited. Floating wind farm technology has become very advanced, with the ability to be installed in very deep water by

assembling turbines on land, and floating them out to sea.

The current Scottish Innovation and Targeted Oil and Gas (INTOG) leasing round will allow developers to build offshore wind farms specifically for the purpose of providing low carbon electricity to power oil and gas installations. This is a great opportunity for oil and gas companies to accelerate their transition into renewables. Traditionally, oil and gas platforms used gas turbine generators to produce the electricity required to run their operations, hundreds of megawatts are required for the heating, pumping, and processing. So, the ability to use wind generated power, is a great way for gas and oil companies to be greener. Using mobile offshore wind farms to serve micro-grids in order to power oil and gas projects could be a potential solution for the whole of the North Sea if proven to work.

Oil and gas companies are experts in building in deep waters, where wind speeds are less volatile enabling wind farms to produce consistent energy. By using their expertise, they are able to expand any renewable aspect of their company, and find innovative solutions to power their own ongoing projects. INTOG will be followed closely by other hydrocarbon producing countries. If it works in the Scottish North Sea the model is likely to be repeated elsewhere, especially in those offshore hydrocarbon production areas of the world where there are currently no offshore wind farms.

Collaboration for the future I have mapped energy developments for decades – September 2022 is the 40th anniversary of the publication of my first commercial map. In renewable energy I started by mapping onshore wind farms here in the UK and Europe over 20 years ago, then offshore wind across the world, and I have observed many trends and developments in the sector. All developments are constantly being mapped and updated, to ensure local markets have access to the most up-to-date picture possible. Currently, it’s estimated that more than 18 million homes are powered by wind energy and with constant developments, this number is set to rise. Ultimately, collaboration between oil and gas companies and renewable energy sources is likely to be a fantastic solution to help them transition.

Britain - Wind Farms

RENEWABLES

17th Ed t on - October 2021

Gallowhill (1.8 MW, 2) Westray Dev. Fund

Spurness Repowering (10 MW, 5) SSE Renewables Hammars Hill (4.5 MW, 5) Hammars Hill Energy Ltd

BURGAR HILL/EVIE

Hammars Hill Ext. (8.4 MW, 2) Hammars Hill Energy Ltd

Burgar Hill 1 (1.5 MW, 1) RWE Burgar Hill 2 (5 MW, 2) RWE Burgar Hill 3 (2.3 MW, 1) Burgar Hill Renewables

N1

N3

Burgar Hill 4 (2.3 MW, 1) Innogy Renewables UK Ltd

N2

NE2

West Hill (Flotta) (2 MW,1) Flotta Wind Power Ltd

Thorfinn (2.75 MW, 1) Vestas/Orkney Sustainable Energy Ltd. Sigurd (1.3 MW, 1) TXU Europe

Hill of Stroupster + Ext (29.9 MW, 13) RWE NE3

N4

Achlachan (10 MW, 5) Achlachan 2 (6.05 MW, 3) Whirlwind Renewables

NE8

NE7 NE4

NE6

WESTERN ISLES

ABERDEEN AREA - NUMBERED WINDFARMS 1. Mains of Auchinderran (1.5 MW, 3) Green Cat Ren. 2. Muirake (4.6 MW, 2) Vento Ludens 3. Bracken Hills (2.3 MW, 1) 4. Culbirnie 1-2 (1 MW, 2) Muirden Energy 5. Gawnmoss (2.4 MW, 3 6. Myreston (1.6 MW, 2) Private) Private) 7. Netherton of Windyhills (4.6 MW, 2) Private 8. Mornflake (2.3 MW, 1) Mornflake Oats 9. Little Hilton Farm (1.6 MW, 2) Landowner 10. Yonderton Wind (4.6 MW, 2) 11. Cairnhill (2.4MW, 3) Greencat Renewables 12. Castle of Auchry (2.4 (2.4 MW, 3) Green Cat R. 13. Gairneston (2.3 MW, 1) 14. Bogenlea (2.3 MW, 1) 15. Hill of Ballquhindacy +Ext (4.25MW,5) Grant Mackie/Greenspan 16. Cloffrickford (2.3 MW, 1) Skelmonae 17. Haddo (4.6 MW,2) Haddo Energy 18. Courstone (2.3 MW, 1) Landowner Project 19. Denhill (2.3 MW, 1) Landowner Project 20. Mackies (2.55 MW, 3) 21. Land to the north west of Hill of Petty (3.6 MW, 4) Fyvie Community 22. St. Johns Well (5.6 MW, 7) 23. Haddo (4.6 MW, 2) Haddo Energy 24. Nth Haddo (1.6MW,2) Green Cat Renewables) 25. Carlincraig (4.6MW,2) Muirden Energy 26. Mains of Hatton (2.4 MW, 3) Eco2 27. Skelmonae (3.2 MW, 4) Landowner Project 28. Woodlands Farm Turbine (1 MW, 2) Landowner 29. Mountwest (2.4MW,3) ESB

NorthConnect Scotland to Norway HVDC Interconnector (1,400 MW) Vattenfall UK, E-CO Energy, Agder Energi (AE) and Lyse Overside/Greenwellhead (9.2 MW, 4) GWEL Operating Company Easter Melrose (1.5 MW, 3) Orkney Sustainable Energy Ltd. Little Blyth (4.5MW, 3) Lovie Ltd Greenhill Croft (4.6 MW, 2) Green Cat Renewable.

Mains of Hatton (2.4 MW, 3) Eco2 Ltd

Boyndie Airfield + Ext (16.3 MW, 8) Falck Renewables SpA

Gowanfold (1.6 MW, 2) Mewstead LLP House O Hill (2.4 MW, 3) Green Cat Renewables St. Fergus Moss (6.9 MW, 3) Greenspan Electric Greenside (9.2 MW, 4) GWEL Operating Company Hill of Glaschyle (27.6 MW, 12) Muirden Energy

HIGHLAND

MORAY

Hill of Petty (3.6MW, 4) Fyvle Community

Inverness

Bruxiehill (1.6MW, 2) Private Nth & Sth Redbog (3.2MW, 4) Private Ednie Farm I-II (2.4 MW, 3) Bruxiehill Wind Energy Ltd. Inverquhomery (1 MW, 1) Muirden Energy West Knock Farm (2.4 MW, 3) Green Cat Renewables

Moy Estate (66 MW, 20) Eneco Wind UK Ltd

Lochcarnan Community Windfarm (6.9 MW, 3) Lochcarnan Community Project Corrimony (10 MW, 5) Corrimony Energy

Corriegarth Estate (69 MW, 23) North British Wind Power Ltd

Hywind Scotland Demonstration Pk. (30 MW, 5) Equinor

Clashindarroch (36.9 MW, 18) Vattenfall Tom Nan Clach Hill of Tillymorgan (5.6 MW, 3) Dorenell (Scaut Hill) (39.1 MW, 17) Community + Burnetts (177 MW, 59) Infinergy Infinergy Upper Wheedlemont Farm (1 MW, 2) Locogen Ltd.

E3

Methlick (9.2 MW,4) Orkney Sustainable Energy Cornabo Wind Cluster (2.7 MW, 3) Landowner Project

Cairnmore (2.55 MW, 3) Greenspan Energy Ltd Millennium South (Glenmoriston) Extension 3 (35 MW, 10) Falck Renewables SpA

Aberdeen

ABERDEENSHIRE

SCOTLAND

Kincardine Offshore WF (50 MW, 6) Grupo Cobra

Mid Hill 1+ 2 (75.9 MW, 33) Fred Olsen Renewables

E3

Drumlithe Feed Mill (7.5MW, 3) East Coast Viners Droop Hill (4.6 MW, 2) Landowner Herscha Hill Wind Cluster (1.6 MW, 2) Muirden Energy Herscha Hill Ex. (1.6 MW, 2) Landowner Project Brownieleys (7.05 MW, 3) Muirden Energy Shiels Farm (7.5 MW, 3) Polar Energy Renewables Tullo T2-T8 (15.5 MW, 7) West Coast Energy Tullo Ext (Twinshiels (7.5 MW, 3) Eneco

Druim Fada (10 MW, 4) North British Wind Power Limited

St. John’s Hill (7.65 MW, 9) SSE

Easter Tulloch (7.5 MW, 3) Engena Brotherton (Paul (Paul Matthew Hill) (4.6 MW, 2) Renewable Energy Ventures

PERTH AND

Tullymurdoch (14.4 MW, 7) Temporis Capital

KINROSS

Welton of Creuchies (9.2 MW, 4) Green Cat Renewables

STIRLING

Earlsburn Ext (Kingsburn) (22.5 MW, 9) Falck Renewables

Allt Dearg (10.2 MW, 12) Allt Dearg Wind Farmers LLP

EAST NORTH DUNBARTON- LANARKSHIRE SHIRE

WEST DUNBARTONSHIRE

Priestside Fm (1 MW, 2) INVERCLYDE Bryce Boyd Planning NORTH Solutions

RENFREWSHIRE

Millour Hill + Ext. (25 MW, 8) Community Windpower

PHASE 3

PHASE 2 Echo

Golf

Hoprigshiels Community Wind Farm (6.9 MW, 3) Aikengall I+ II (108.8 MW, 35) Berwickshire Community Renewables LLP Community Windpower Ferneylea Farm (1.5 MW, 2) Landowner (private or company)

E. LOTHIAN

EDINBURGH

Penmanshiel (28.7 MW, 14) RES Moorhouse Farm (1 MW, 2) Urban Wind Tormywheel 2 (5 MW, 2) Muirhall Energy Tormywheel (30.8 MW, 15) Muirhall Energy

MIDLOTHIAN Pearie Law (19.2 MW, 6) EDF ER Pogbie Farm (5.1MW, 6)

Fallago Rig (144 MW, 48) EdF

Blantyre Muir+ Ext. (12.3MW, 6) WCE

Neilston (10 MW, 4) EAST RENFREWSHIRE Carbon Free Dev. Middleton (12 MW, 6) RWE

Turbine Test Facility (NOWTTF) (13 MW, 2)

Berwick Bank (1140 MW - 4000MW, 240) SSE Renewables)

Mossmorran (4.6 MW, 2) Airvolution Energy

FALKIRK

Greendykeside (4 MW,W. 2) LOTHIAN A7 Energy Ltd

GLASGOW

AYRSHIRE

Delta

PHASE 2

Rosehill (2.4 MW, 3) Green Cat Todhill (11.4 MW, 4) Falkirk TodHill Wind Ltd

W1

Shearwater 1, (3000MW) Shearwater Energy

PHASE 3

Inch Cape (1080 MW, 40-72) Red Rock Power (SDIC)/ESB

FIFE

Skeddoway Fm (1.5 MW, 1) Green Cat Renewables Earlseat (16 MW, 8) Bonerbo (2.7 MW, 3) Carbon Free Landowner project Developments Collier Goathill Quarry Levenmouth Turbine (7MW, 1) (1.5 MW, 1) Wind Direct ORE Catapult CLACKMANNANSHIRE Westfield (10 MW, 4) Infinis Gibsley Fm (1.5 MW, 1)

A’Chruach (43.05 MW, 21) Infinis

Bravo

Foxtrot

Dundee Perth Strathallan (20.7 MW, 9) Green Cat Renewables

ARGYLL AND BUTE

A’Chruach II (4.1 MW, 2) Infinis

Alpha PHASE 1

Carraig Gheal (Loch Awe) (46 MW, 20) GreenPower (International) Ltd.

Barran Caltum E33 Wind Turbine (1.23 MW,2) Barran Caltum Co-operative Wind Ltd

Seagreen 1a (500 MW, 36) SSE Renewables)

Frawney (Resubmission) (4 MW, 5) Polar Energy (Finlarg) Ltd

Calliachar (32.2 MW, 14) I & H Brown Ltd/SSE

E1

Seagreen 1 (1140 MW, 114) SSE Renewables)

ANGUS

Ark Hill (6.4 MW, 8) Green Cat Renewables

Calliachar North (21 MW, 7) I&H Brown

Brockholes (2.4 MW, 3) Landowner Project

Keith Hill (4.5MW, 5) P

Berwick-upon-Tweed 5.

33.

Sneddon Law (30 MW, 15) Community WP 34.

GlaxoSmithKline (7.5 MW, 3) GlaxoSmithkline Calder Water Community WF 2.

(39MW, 13) Dungavel Hill (29.9 MW, 13) E.ON Nutberry Hill (15 MW, 6) Falck Renewables Galawhistle (66 MW, 22) Infinis Hagshaw Hill+Ext (67.6MW,66) SPR

Ayr SOUTH AYRSHIRE

Galashiels

S. LANARKSHIRE

BORDERS

Penbreck (30.6 MW, 9) PNE

Middle Muir 51 MW, 15) Banks Dev.

Wandylaw (20.5 MW, 10) Blue Energy Wind Limited

Langhope Rig (16 MW, 10) SSE Renewables

Clyde (Nth/Central) 220.8 MW, 152) SSE Clyde Sth (128.8 MW, 56) SSE Crookedstane (9.2 MW, 4) 2020 Renewables

Dersalloch Chapelton Farm (2.55 MW, 3) Thrive Renewables (69MW,23) SPR Brochloch Rig (Windy Standard 2) (61.5 MW, 30) Fred Olsen/RWE

Under Constrution North Sea Link (NSN) England to Norway Interconnector (1,400 MW) National Grid & Statnett SF

Twenty Shilling Hill (37.8MW, 9) Element Power Afton (50 MW, 25) E.ON

Assel Valley (25 MW, 10) Falck Renewables

Wingates (15 MW, 6) Ventient Energy

Blyth Offshore Wind Demonstration Site (Array 3a & 4 ) (58.4 MW, 10) EDF

Lynemouth (26 MW, 13) SPR

Morpeth

Green Rigg (36 MW, 18) EDF Energy Renewables

Ewe Hill +Ext (50.6MW,22) SPR

Blyth

Blyth Offshore Wind Demonstration Site (Array 2) (41.5 MW, 5) EDF

Solwaybank (30 MW, 15) RES

Dumfries

DUMFRIES AND GALLOWAY

Ponteland

Beck Burn (31.05 MW, 9) EDF Hallburn (1

NORTHERN

Whitley Bay Tynemouth South Shields

Gosforth

NEWCASTLE UPON TYNE

Boundary Lane (6 MW, 3) EdF ER

Glenchamber (25.3 MW, 11) RES

Durham

DURHAM

Penrith

Sofia (1400 MW, 100) RWE

Washington

Consett

RELAND

Dogger Bank B (Creyke Beck B) (1235MW, 95) SSE Renewables, Equinor

TYNE & WEAR

SUNDERLAND

Stanley

Siloth

Jarrow

Gateshead

Kiln Pit Hill (13.8 MW, 6) RWE

Carlisle

Operational Moyle Interconnector Northen Ireland to Scotland (500 MW) (HVDC) Mutual Energy

Dogger Bank C (Tranche B) (1218 MW, 87) SSE Renewables, Equinor

Bewick Drift (2.35 MW, 1) Harworth Power

NORTHUMBERLAND

Tralorg (18.8 MW, 8) PNE Wind

Peterlee

Dogger Bank A (Creyke Beck A) (1235MW, 95) SSE Renewables, Equinor

Spennymoor Met Mast

Billingham Redcar Lambs Hill (8 MW, 4) Banks Developments

Whitehaven

Stocktonon-Tees

Moor House (Resubmission) (12.3 MW, 6) Banks Developments

Appleby-inWestmorland

Middlesbrough

Darlington

Seamer 2 (4.1 MW, 2) Broadview Energy Ltd

Whitby

Seamer (10.25 MW, 5) Ventient Energy

CUMBRIA Isle of Man Offshore Wind Farm (700 MW) Dong Energy AS

Kendal

Northallerton

Scarborough

NORTH YORKSHIRE Isle of Man

Ulverston

ENGLAND

Barrow-in-Furness

Operational Isle of Man Interconnector (40 MW) (AC) Manx electricity Authority

Heysham

Ripon

Carnaby (4 MW, 2) FMC Environmental

Knaresborough

Lancaster University (2.35 MW, 1) Lancaster University

Halifax Brighouse

Darwen

Southport

Skelmersdale Formby

Gwynt y Mor (576 MW, 160) RWE Innogy Gwynt y Mor Ext. (576 MW) RWE Innogy

Holyhead Colwyn Bay

Llandudno Conwy

ISLE OF ANGLESEY

Rhyl

Doncaster

Frodsham

Northwich

Stockport Cheadle

FLINTSHIRE

CHESHIRE

Chester

Macclesfield

DENBIGHSHIRE

Burton upon Trent

Brownhills

Stourbridge

Halesowen

Aberystwyth

Stourporton-Severn

CEREDIGION

CARMARTHENSHIRE Princes Gate Spring Water (1.6 MW, 2) Locogen Ltd

Gloucester Maesgwyn Ext (7.5MW,Merthyr 3) Pennant

Ammanford Mynydd y Gwair (32.8 MW, 16) Innogy

Skomer Island

Milford Haven

Llanelli

Pembroke

Caldey Island

Abergavenny

Tydfil

GLOUCESTERSHIRE

MONMOUTHSHIRE

BLAENAU GWENT TORFAEN

Stroud

SWANSEA

Port Talbot

Pontypridd Caerphilly

BRIDGEND

Nash WTW (2.5MW,1) Welsh Water

CARDIFF

Bridgend

CARDIFF

Ilfracombe

Henleyon-Thames

Swindon

BRISTOL

Frome

Warminster WILTSHIRE

Barnstaple

Salisbury

Tiverton

Ringwood

DORSET

DEVON

Longstones (4.1 MW,1) Cleanearth Energy

Truro St Ives

Penzance

Redruth

St Austell

Fowey

Christchurch

Bournemouth

Weymouth

Exmouth Dawlish

Newton Abbot

Poole Dorchester

Sidmouth

CORNWALL Bodmin Woodlands Barton (5 MW, 2) Hendra Manor Ltd

Bridport

Exeter

Hythe

Fareham Gosport Cowes

New Milton

Newport

ISLE OF WIGHT

Sevenoaks

Oxted

Horsham

Bembridge Sandown

Bognor Regis

Worthing Littlehampton

Brighton

PLYMOUTH Plympton

Torpoint

Rampion (Hastings) (400.2 MW, 116) E.ON UK Renewables

Paignton Brixham

Garlenick Estate (4 MW, 2) Airvolution Energy

Camborne Falmouth Helston

Isles of Scilly

B

a n W nd Fa ms

Bexhill Hastings

Eastbourne

Rampion Ext. (1200MW,116) E.ON UK Renewables

Torquay

Saltash

Hailsham

Newhaven

Seaford

Submitted Interconnexion France-Angleterre (IFA2) Central Coast of UK - Normandy Region of France (1,000 MW) (HVDC) National grid Interconnectors Limited & Réseau de Transport dÉlectricité

Teignmouth

ElecLink -UK -UK to France Interconnector (1,000 MW)

Hythe

E. SUSSEX

Hove

Dover

Ashford

RENEWABLES

SPONSORED BY

Folkestone

Operational Interconnexion France - Angleterre (IFA) (2,000 MW) (HVDC) National Grid Interconnectors Limited & Réseau de Transport dÉlectricité

Uckfield

Lewes Chichester

Nemo Link UK to Belgium Interconnector (1,000 MW) (HVDC) National Grid Nemo Link Ltd. & Elia Group

Deal

Crowborough

Haywards Heath

Portsmouth

Ramsgate Canterbury

Tunbridge Wells

East Grinstead

Crawley

W. SUSSEX

Margate

Herne Bay

Maidstone

Tonbridge

Waterlooville

Fawley

Lymington

Redhill

KENT

Petersfield

Eastleigh

SOUTHAMPTON

Isle of Sheppey

Sittingbourne Faversham

SURREY

Winchester Romsey

Yeovil

Sheerness

Chatham

Godalming

Alton Haslemere

SOMERSET Taunton

Dorking

Guildford

Farnham

HAMPSHIRE

East Youlstone Farm (4 MW, 2) Airvolution Energy

Reigate

Aldershot

Andover

Tilbury

Swanley

Croydon

Epsom

Leatherhead

Basingstoke

Foulness Rayleigh Island Southend-on-Sea

Dartford Gravesend

LONDON

Woking

BritNed Link UK TO Belgium Interconnector (1,000 MW) (HVDC) National Grid & TenneT

Maldon

Brentwood Basildon

South Benfleet Canvey Island

GREATER Woolwich

Kingston upon Thames Sutton

Camberley

Bridgwater

Bideford

Richmond

Staines Bracknell

Devizes

Chelmsford

Chigwell

LONDON

Uxbridge

Windsor

Trowbridge

Burnham-on-Sea

Minehead

Melksham

Slough

ESSEX Harlow

Clacton-on-Sea

Witham

Waltham Abbey

Barnet

Harrow

Marlow

Reading

Newbury

Felixstowe Harwich

Colchester

Braintree Bishop's Stortford

Ware Hertford Hatfield Hoddesdon Cheshunt Enfield

Watford

Beaconsfield

Maidenhead

BERKSHIRE

Chippenham

Bath

Tring

Amersham

High Wycombe

Saffron Walden

Stevenage

HERTFORDSHIRE

Welwyn Garden City Hemel Hempstead St Albans

Berkhamsted

Thame Abingdon

Bristol Port WP Ext.(9 MW,3) Bristol Port Co. Bristol Sewage Treatment Works (8.2 MW, 4) Triodos Renewables

Clevedon

Weston-Super Mare

Denzell Downs (Resub.) (10 MW, 5) REG Windpower

Royston

Ipswich

Sudbury

Letchworth

Hitchin

Luton

Dunstable

Aylesbury

Oxford

Didcot

Solutia UK (5 MW, 2) Wind Direct

Mynydd Portref (Taff Ely Ext) (9.35 MW, 11) VALE Tegni Cymru Cyf OF Mynydd Portref Ext (12 MW,6) GLAMORGAN REG Windpower Barry

Lundy

Witney

Cirencester

NEWPORT

Fforch Nest WF 1+2 (27.5 MW, 11) Pennant Walters Newton Down (5 MW, 2) Renewables Energy Partnerships Porthcawl

Sharpness Docks (2 MW, 1) Partnerships for Renewables Chepstow

Cwmbran

CAERPHILLY

Neath

Swansea

Kidlington

East Anglia 2 (900MW, 65) Scottish Power Renewables

Stowmarket

SUFFOLK Haverhill

Milton Keynes

BUCKINGHAMSHIRE

Bicester

Bury St Edmunds

Newmarket

Bedford

Leighton Buzzard

OXFORDSHIRE

Thetford

Ely

Cambridge

BEDFORDSHIRE

Newport Pagnell

Banbury

Cheltenham

Carmarthen

East Anglia 1 NTH (800MW, 58) Scottish Power Renewables

CAMBRIDGESHIRE Mildenhall

St Neots

Airfield Farm (8.55 MW, 3) Airvolution Energy

NORTHAMPTONSHIRE

Tewkesbury

Ramsey Island

Skokholm Island

TCI Renewables

M1 (Roade) (7.2 MW, 9) EdF ER

Stratford upon Avon

Evesham

Hereford

PEMBROKESHIRE

?

Northampton

WARWICKSHIRE

Worcester

Woolley Hill (10 MW, 4) RES Huntingdon St Ives

Burton Wold South Kettering (8.25 MW, 3) Winwick Infinergy/Muirhall E. (12.3 MW, 6) E.ON Watford Lodge Rushden (10.25 MW, 5) Volkswind Common Barn ) (6.2 MW, 3)

Daventry

East Anglia 3 (1400 MW,100) Scottish Power Renewables

Lowestoft

March Boardinghouse Farm (10.25 MW, 5) Ecogen Ltd. Greenvale AP (1.5 MW, 1) Wind Direct

Kelmarsh (12.3 MW, 6) E.ON UK

Rugby

Redditch

Great Malvern

Bedworth

Lilibourne (10 MW, 5) Energiekontor

East Anglia 5 - East Anglia Array Norfolk Vanguard (1800 MW, 90) Vattenfall

Norwich

Peterborough Corby

Market Harborough

COVENTRY

Blood Hill - Repower (0.8 MW, 2) E.ON Renewables

East Dereham

Swaffham

Great Yarmouth

Wigston

Hinckley

Leamington Spa Warwick

WORCESTERSHIRE

HEREFORDSHIRE

LEICESTERSHIRE Nuneaton

M1 J18 Wind Turbines (4 MW, 2) Airvolution Energy Ltd.

Bromsgrove

Droitwich

POWYS

LEICESTER

BIRMINGHAM

Solihull

Kidderminster

Wisbech

Stamford

Sutton Willenhall Coldfield West Bromwich WEST MIDLANDS Dudley

?

?

King's Lynn

RUTLAND

Tamworth Aldridge

Walsall

WOLVERHAMPTON Bridgnorth

NORFOLK

Melton Mowbray

Cannock Lichfield

Telford

Chiplow (8.2 MW, 4) E.ON UK Renewables

Spalding

Loughborough

Ashby-dela-Zouch

Jack’s Lane (15 MW, 6) RES

Grantham

NOTTINGHAM

Long Eaton

Rugeley

South Staffordshire College (Rodbaston) (4 MW, 2) REG Windpower

SHROPSHIRE

Beeston

DERBY

Boston

Stoke Bardolph Farm (2.5 MW, 1) Severn Trent Water

Ilkeston

Shrewsbury

WALES

Hawton (9 MW, 3) Bolsterstone PLC

Hucknall

Eastwood

Stone Uttoxeter

Stafford

East Anglia 6 - Norsk Boreas (1800 MW, 90+ ) Vattenfall

Newark-on-Trent

STOKE-ON-TRENT

Newport

LINCOLNSHIRE

Sutton in Mansfield Ashfield

Ripley

STAFFORDSHIRE

?

Lincoln

NOTTINGHAMSHIRE

Leek

WREXHAM

Bardsey Island

Dudgeon East (402 MW, 67) Equinor

Staveley

Kidsgrove

Lower Hanyards Farm (0.5 MW, 1) Revolution NRG

Dudgeon East Ext. (402 MW, 34) Equinor

Race Bank (573 MW, 91) Ørsted A/S

Chesterfield

Newcastleunder-Lyme

Oswestry

GWYNEDD

Race Bank EXT (573 MW) Ørsted A/S

Louth

Clay Cross Matlock

Biddulph

Triton Knoll (860 MW, 90) RWE

Gayton le Marsh (16.4 MW, 8) Energiekontor UK Ltd.

Gainsborough

Retford

Worksop

Dronfield

DERBYSHIRE

Buxton

Congleton Sandbach Crewe

Nantwich Wrexham

HUMBERSIDE

Rotherham

SHEFFIELD

Flint

CONWY

Bishopthorpe Farm (16.4 MW, 8) Baywa

Stocksbridge

S . Y O R K SH I R E

Glossop

Warrington Widnes Knutsford Runcorn

Ellesmere Port

Abergele

Bangor

Barnsley

MANCHESTER Sale

Altrincham

LIVERPOOL

Birkenhead Garston

Prestatyn

Hemsworth

Rochdale Bury Bolton Middleton

Salford

St Helens

MERSEYSIDE

Hornsea Project 3 (2400+MW, 160+) Ørsted A/S

Viking Link (UK to Denmark Interconnector) (1,000 MW to 1,400 MW) (HVDC) National Grid Interconnector Holdings Limited & Energinet.dk

HULL

Far Marsh (7.5 MW, 3) Mr Wielkopolski Immingham Grange (Flixborough) (12.3 MW, 6) Blue Energy Wind Limited Grimsby Newton Marsh Treatment Works (4.6 MW, 2) Scunthorpe Cleethorpes ACS Renewables Ltd.

Thorne

GREATER MANCHESTER

Kirkby

Bootle Wallasey

3.

1.

Goole

Wakefield

Huddersfield

Standish Ormskirk Wigan

Crosby

Ysgellog Farm (4.6 MW, 2) Airvolution Energy

Hornsea Project One (1218MW, 174) Ørsted A/S

Withernwick Extension (8.2 MW, 4) Energiekontor UK Ltd.

Beverley Selby

Garforth

Dewsbury

Chorley

Operational East-West Interconnector (Deesside - Woodland) (500 MW) (DC) EirGrid

Gallymoor Landfill (1.8 MW, 2) FCC Environment

Tadcaster

LEEDS

W. YORKSHIRE

Blackburn

Hornsea Project Four (1000 MW, 180) Ørsted A/S

EAST RIDING OF YORKSHIRE

York

Otley

Bingley Shipley

BRADFORD

Burnley

Preston

Holy Island

Ilkley

Keighley Yeadon

LANCASHIRE

Blackpool

Lytham St Anne's

IRELAND

Harrogate

Skipton Ovenden Moor Repower (18 MW, 9 ) E.ON UK

Fleetwood Western Link (HVDC) Scotland to North Wales (2,200 MW) National Grid plc & ScottishPower Transmission

Hornsea Project Two Breesea (1386 MW, 92+) Ørsted A/S

Bridlington

Heysham Moss (1.5 MW, 1) BT Lancaster

38

CONTRACT AWARDS

SPONSORED BY

Infinity Partnership: Your Partner in Business Infinity Partnership is an award-winning, multi-disciplinary accountancy and business advisory practice, with a proactive approach to customer service.

www.infinity-partnership.com

Subsea 7 awarded contract offshore Norway

Infinity has been a five-time winner at the British Accountancy Awards and has been a three-time finalist at the Scottish Accountancy Awards in recent times.

manifold. The contract scope includes engineering, procurement, construction and installation (EPCI) of the pipelines, spools, protection covers and tie-ins using key vessels from Subsea 7’s fleet. The production pipeline is a pipe-in-pipe design.

Project management and engineering will commence immediately at Subsea 7’s offices in Stavanger, Norway. Fabrication of the pipelines will take place at Subsea 7’s spoolbase at Vigra, Norway and offshore operations are expected to take place in 2023 and 2024.

Subsea 7 announced the award of a sizeable1 contract by Aker BP for the Trell & Trine field development, located in the Alvheim area of the North Sea. The project involves a subsea tie-back of approximately 21 kilometers to the Alvheim FPSO, via the existing East Kameleon subsea

Monica Th. Bjørkmann, Vice President for Subsea 7 Norway said: “This award is a continuation of Aker BP’s exciting development of the Alvheim area. The Trell & Trine field development is an excellent example of how our collaboration with Aker BP and Aker Solutions, through the Aker BP Subsea Alliance2, builds upon our collective experience from previous and ongoing projects. The partnership enables Subsea

McDermott Scores FEED Work On Viva Energy Refinery In Australia of 2024. Lower sulfur gasoline will support improved vehicle emissions.

U.S. engineering giant McDermott International has been awarded a Front-End Engineering Design (FEED) contract from Viva Energy Australia as part of its Geelong Refinery project to provide additional desulfurization capabilities.

"This award is a testament to our successful execution of the pre-FEED. In this next phase, we will apply McDermott's extensive modularization expertise to ensure quality, reduce cost and maintain the schedule," said Tareq Kawash, Senior Vice President for Onshore of McDermott.

"We look forward to continuing to support Viva Energy Australia's carbon emission reduction goals to provide cleaner fuels and enhance Australia's fuel security."

According to the company, work on the project will be executed from McDermott's engineering center of excellence in The Hague, the Netherlands with support from its offices in India and Australia.

McDermott said that the award followed the successful completion of the Pre-FEED activity and encompasses early engineering and procurement services to support the project schedule.

Viva Energy’s Geelong Refinery began operations in 1954. Today it’s one of two refineries remaining in Australia, employing around 700 people, and supplying over 50% of Victoria’s and 10% of Australia’s fuel.

Under the contract scope, McDermott will provide FEED services for a new modularized production unit. The unit will produce ultra-low sulfur gasoline with up to ten parts per million of sulfur to meet the proposed changes to Australia's fuel quality standards from the end

The refinery can process up to 120,000 barrels of oil per day, manufacturing petrol, diesel, LPG, jet fuel, avgas, bitumen, specialty solvents for a wide range of industries, and low aromatic fuel to support Australia’s Federal Government’s petrol-sniffing prevention program.

www.ogv.energy I September 2022

7 to engage early in the field development process, optimising design solutions and contributing to a positive final investment decision. Subsea 7 is looking forward to continuing our collaboration for the Trell & Trine field development, with a focus on safe, efficient and reliable operations.”

Wood to engineer Europe’s most innovative olefin complex

Wood, the global consulting and engineering company, has secured a new contract with INEOS in excess of $100 million to deliver engineering, procurement, and construction management (EPCm) services for Project One, a new state-of-the-art petrochemicals complex in Antwerp, Belgium, which will deliver an ethane cracker with the lowest carbon footprint in Europe.

Effective immediately, the four-year contract will be delivered by Wood’s Projects business unit. The scope is focused on the outside battery limit facilities for the ethane cracker and follows the successful completion of frontend engineering design for the facility.

Wood’s integrated project management team will also continue to oversee the project, working closely with the INEOS project team.

Giuseppe Zuccaro, President of Process & Chemicals at Wood, said: “The chemicals sector, like all industries, is forging its own path to carbon neutrality. What Project One represents is the next era of ethylene production, a key component in most plastics. Through the combination of technology and an innovative technical design approach, it will be the most sustainable and energy-efficient steam cracker in Europe.

“We are proud to have the opportunity to build on our strong relationship with INEOS by continuing to deliver on this major capital project, deploying the extensive petrochemicals expertise of our global engineering and project delivery teams.”

At its peak Wood is expected to employ around 300 people on the project across its execution centres in Reading and Milan, its global engineering centre in India, and at the site in Antwerp during construction.

CONTRACT AWARDS PD&MS awarded threeyear contract to support Vattenfall’s European operations Aberdeen-headquartered PD&MS Group has secured a three-year operations and maintenance (O&M) contract with Vattenfall to support its European offshore wind portfolio for an undisclosed sum.

The contract, which also has options to extend for a further two-year period, will see the leading international engineering, procurement, construction and commissioning (EPCC) specialist providing a wide range of key support across the developer’s windfarms in the United Kingdom, The Netherlands, Sweden and Denmark.

This award underpins PD&MS’ ever-growing position as a key supplier in O&M and inspection in the offshore wind sector, and builds on the success of the safe and efficient delivery of several onshore and offshore wind projects for its clients including SSE Renewables and Moray East Offshore Windfarm.

“We are thrilled that Vattenfall has recognised our highly transferable skills gained from years of successfully operating across oil and gas and other energy sectors and chosen us as one of their long-term service providers. This new contract solidifies PD&MS’ position as a key supplier for future wind developments, such as ScotWind and other future European projects.”

Now in its 20th year, PD&MS is a multidiscipline EPCC contractor and has been delivering mid-value capital projects, O&M, general modifications, upgrade projects, late life asset management and decommissioning services across the energy sector. It currently employs around 550 in Scotland and 100 overseas, with operations in Aberdeen, Glasgow Azerbaijan.

The firm’s energy transition credentials have grown significantly in the past few years. As well as expanding its offshore wind clients’ portfolio, it was recently granted ORE Catapult’s Fit 4 Offshore Renewables status for its EPC services. The programme was developed to help the UK supply chain to reconfigure and deliver services in the offshore renewable energy sector. In the last 12 months, the business has also acquired low carbon engineering specialists Synergie Environ and front-end consultancy Optimus.

Thomas Barter head of renewables business development at PD&MS said:

Mark Davidson, project director and energy transition leader at PD&MS, added: “Winning this three-year minimum contract with Vattenfall following a competitive tender process is testament to our team’s connected competencies which match the disciplines needed by offshore wind. We have an extensive track record for delivering innovative and costeffective project solutions which have proven to reduce cost and maximise asset uptime to create significant ongoing value within the offshore renewable energy sector. Underpinned by our flexible proactive culture we are well placed to further service the UK and European decarbonisation agenda.”

PD&MS was founded in 2002 and is owned by private equity firm Inflexion, which completed a secondary buyout in 2014.

Petrofac, GCB bag $300mn EPC deal for Algerian gas project A joint venture between Petrofac and Genie Civil et Batiment has been awarded an engineering procurement and construction contract worth $300mn from Algeria's Sonatrach for the Tinrhert EPC2 gas project in the north African country, Petrofac said.

The project, situated in Alrar, covers the construction of a new central processing facility with inlet separation and decarbonisation units, as well as tie-ins to existing separation and boosting facilities at the site that Petrofac helped build in 2018. The two companies will also be responsible for commissioning, start-up and performance testing.

Once completed, the project will ramp up gas production and remove CO2 from the field's gas reserves.

"The Petrofac and GCB consortium is testament to our focus on local delivery, through investment

in local supply chains and work forces," the chief operating officer for Petrofac's engineering and construction division, Elie Lahoud, commented.

"We are very pleased to have been notified of this provisional award by Sonatrach, which reflects their confidence in our ability to drive in-country

value, whilst safely delivering strategically significant energy infrastructure.”

Petrofac, which has been working in Algeria for decades, said its share of the contract was worth $200mn.

CONTRACT AWARDS SPONSORED BY

39

40

ON THE MOVE

SPONSORED BY

www.normanbroadbent.com We have a simple and straightforward objective: to help our clients manage and successfully drive change, mitigate risk, grow, and succeed.

Luke Horrigan, Client Partner Luke is a Client Partner within our Industrials practice, bringing over 15 years’ experience in search, talent acquisition and recruitment. He is specifically focused on the civil aviation, rail, road & logistics and natural resources sectors. Luke has refined his stakeholder management skills through a varied career which has seen him support customers across APAC & EMEA, having setup offices in the UK, Scandinavia & Australia. His career has covered the oil & gas, mining, renewables, digital & tech and professional services industries. Luke has worked in most areas of talent acquisition from contractor recruitment to retained search. He has also worked on in-house assignments, giving him a unique view of the challenges and expectations faced by clients. He is passionate about diversity & inclusion, having been a key figurehead in previous organisations and driving new and innovative approaches. Luke holds a BSc Hons degree in Business Studies, alongside a Diploma in Recruitment Practice from the University of Middlesex.

Tufan Erginbilgi

1

Apache (Nasdaq: APA) has named the previous deputy CEO of BP as its new chairman

H. Lamar McKay takes over the position on September 1 from John Lowe who has introduced his retirement. The 63-yearold was appointed to the Apache board in February 2021, having joined the agency from BP the place he was chief transition officer from October 2019.

Previous to that he served because the deputy CEO at BP from February 2016.

Since starting his profession in 1980 with Amoco, different roles have included serving as CEO of the worldwide upstream enterprise at BP and dealing as chairman and president of its America enterprise. Outgoing Mr Lowe stated: “We’re happy to announce Lamar might be assuming the position of APA board chair following my retirement.

2

Rolls-Royce names ex-BP executive as CEO to succeed Warren East

Rolls-Royce has named BP veteran Tufan Erginbilgic as its next chief executive officer, replacing Warren East when he steps down at the end of this year. Tufan Erginbilgic, 62, spent 20 years at BP Plc, and in his most recent role before leaving in 2020 led the firm's downstream business, responsible for refining, petrochemicals and service-station activities, London-based Rolls said in a statement Tuesday. He is currently a partner at privateequity firm Global Infrastructure Partners.

The company said in February that East was set to leave at the end of 2022 after more than seven years at the helm, during which he led the jet-engine maker through a punishing period capped by the Covid-19 pandemic.

Erginbilgic will take up his new role on Jan. 1.

4

“Lamar is a revered chief within the trade, with over 40 years of worldwide pure gasoline and oil expertise, and his appointment is a testomony to his wonderful working relationship with all of our board and senior administration.

“On behalf of the complete board, we welcome Lamar as our subsequent board chair.”

Amanda Blanc

www.ogv.energy I September 2022

Chris Smith, Partner

David Cook

3

David Cook appointed MD of Storegga’s new Americas business

Storegga, the independent UK decarbonisation developer, has today launched a new Americas business. The Storegga Americas business will seek and develop decarbonisation and clean fuel opportunities across the region, including the US, Canada, Latin America and the Caribbean.

The Storegga Americas business has ambitious plans to scale up quickly. David Cook is leading the business, with the support of Randy Wheeler. David joins following his CEO role at the Norwegian Energy Company ASA (Noreco). David is a broadly experienced energy industry executive with substantial international leadership experience, having held senior positions in oil and gas upstream and midstream businesses and renewables. Prior to Noreco, David held executive roles at businesses such as INEOS, Orsted, TAQA and BP.

Aviva CEO Amanda Blanc joins BP as non-executive director

Amanda Blanc has been Group CEO of Aviva plc, the UK's leading insurance, wealth and retirement business, since 2020. She was formerly Group CEO at AXA UK, PPP & Ireland and a previous CEO of Europe, Middle East, Africa & Global Banking at Zurich Insurance Group. She has also held executive leadership positions at Towergate Insurance Brokers, Groupama Insurance Company, and Commercial Union. Amanda is co-chair of the UK Transition Plan Taskforce, which is developing a gold standard for UK firms’ climate transition plans. Helge Lund, chair of bp, said: “Amanda’s appointment reflects our continued commitment to strengthen the composition of bp’s board. The skills and experience Amanda brings will further enhance our ability to support bp as it transforms into an integrated energy company.”

ON THE MOVE

5

41

The North Sea Transition Authority (NSTA) has announced what is thought to be one of the first nonexecutive director job share positions on a UK board

The position is being shared by Fiona Mettam and Vicky Dawe, who also job share the role of Director of Energy Development and Resilience at the Department for Business, Energy and Industrial Strategy (BEIS).

The post holders are a representative of the Secretary of State for BEIS, the NSTA’s sole shareholder, as an NSTA board director.

The Secretary of State gave approval to amend the NSTA’s Articles of Association to allow the appointment of an additional ‘alternate director’ on the NSTA board. It is believed to be the first time this has happened for a body such as the NSTA across all government departments.

Directors are responsible for setting the NSTA’s strategic direction, policies and priorities.

Chaired by Tim Eggar, the NSTA board met eight times in 2021-22, and seven board meetings are scheduled for 2022-23. Directors also attend a number of other meetings with stakeholders.

Katya Zotova

8 Jay Abercrombie Jordan Ferguson

6

H2scan appoint Jordan Ferguson as European Director

Aberdeen-based businessman Jordan Ferguson has joined the company as European Director and will direct the company’s expansion in Europe, as they broaden their focus into the growing hydrogen economy.

Jordan brings a wealth of experience having worked in several commercial roles including managing corporate development and acquisitions for Hutcheon Mearns, COO for Valor Energy Group, and higher management roles at TDC Parsons Peebles and Sulzer.

Jordan also continues his role as Founding Director for UK business consulting firms Imperium Experts and Bio Technical Limited and will continue to play an active role successfully driving business growth – focusing on various markets including carbon capture technologies, biowaste recycling, and biogas.

7

TCO announce the appointment of Robert Jay Abercrombie as its new CEO

TCO, a Norwegian energy sector company focused on redefining well solutions, has announced the appointment of Robert Jay Abercrombie as its new CEO. An expert in petroleum engineering, leadership and strategy, Robert has more than 14 years’ experience within the energy sector. His appointment falls at an exciting time for the service provider as it looks towards increased organizational growth within key markets.

Robert, who studied Electrical and Electronics Engineering while being a professional Ice Hockey player with the Stavanger Oilers, transitioned into the energy sector in 2008.

He joined TCO in 2013, having initially worked as a product manager for its chemical injection product line. From there, he was promoted into senior managerial positions including Vice-President of Global Sales and Chief Operating Officer.

Manufacturing company Harland and Wolff (LON: HARL) announced the appointment of a new board member

Former Shell (LON: SHEL) CEO Katya Zotova will join the company’s top team as a Non-Executive Director, effective September 1.

She has 25 years of experience in strategy and business development, investment banking and private equity.

In addition to working for oil giant Shell, where she held various strategy and M&A positions, Ms. Zotova has worked for LetterOne Energy, Pamplona Capital and Citigroup.

From 2014 to 2022, she was a non-executive director at Vedanta Resources, a more than $10 billion global diversified natural resources company.

Ms. Zotova is currently an advisor at Antler, a global early-stage venture capital fund, and was most recently Managing Director of financial services firm Mizuho International.

She holds an MBA from the Rotterdam School of Management and an executive program in disruptive innovation from Harvard Business School.

Content provided by Norman Broadbent

42

DECOMMISSIONING

SPONSORED BY

www.wellsafesolutions.com

SAFE, SMART & EFFICIENT The complete package for well decommissioning Well-Safe Solutions provides a ground-breaking approach to the safe and cost-efficient decommissioning of on and offshore wells. We offer a specialist well abandonment service that allows operators to meet the challenges and regulatory imperatives around decommissioning, while significantly reducing costs.

Mermaid, EXCEED gearing up for ‘landmark’ P&A campaign in North Sea early this month via Reach Subsea, as Mermaid Subsea Service charters the vessel for the decommissioning campaign.

At the end of June, Mermaid Subsea Services and EXCEED Energy announced the award of the vessel-based P&A campaign on behalf of four operators.

EXCEED Energy said this is the company’s largest vessel-based well P&A campaign to date. At the same time, it represents Mermaid’s entry into the North Sea marketplace.

Mermaid Subsea Services (UK) Ltd and its partner EXCEED Energy are awaiting the arrival of DP2 construction vessel Olympic Challenger to kick off a landmark multi-operator vesselbased plug and abandonment (P&A) campaign in the North Sea. According to a social media update, the Olympic Challenger will arrive at the Port of Aberdeen

Due to commence in three weeks’ time, the multi-operator vessel-based campaign is described as one of the largest of its type to be undertaken on the UK Continental Shelf (UKCS) for at least a decade.

It currently comprises the decommissioning of ten exploration and appraisal (E&A) wells across the Northern, Central and Southern North Sea.

Based on the campaign approach, which has been highlighted as an important lever in the cost reduction of well P&A, the potential for this to become a multi-operator programme was the objective upon which the partnership was founded, the companies said.

The North Sea Transition Authority (NSTA) is actively promoting multi-operator welldecommissioning campaigns as they can deliver cost efficiencies, reduce emissions and give suppliers confidence to invest.

In order to support such campaigns, NSTA created a map and a dataset of assets to back four North Sea operators in their ambition to reduce subsea decommissioning costs by 50%.

Meanwhile, six oil and gas operators in The Netherlands are working with Oceaneering Services in the first joint campaign to decommission 24 standalone mud line suspension (MLS) wells in the Dutch North Sea.

Stena Drilling names Dillan Perras as Wells Manager and Director of new start-up company Stena Drilling Limited announced that the company has appointed Dillan Perras as Wells Manager – and Director of Stena Wells. The first member of the new start-up - leading the company to provide fully managed well construction and decommissioning.

Dillan Perras joins Stena Drilling after 16 years with Talisman / Repsol / Repsol Sinopec Resources where most recently he held the role of Drilling & Completions Manager.

Mr Perras has over 20 years of experience in the sector leading teams in the North Sea, Peru and Canada before returning to the North Sea in 2016. Dillan has led teams delivering all aspects of well operations from engineering and planning through to intervention, drilling, completions and decommissioning. Having delivered projects in the deep jungle to the deep sea he is well placed to lead the new company forward.

As director of Stena Wells, Mr Perras will lead the new company on its way to delivering fully managed well construction and decommissioning campaigns on behalf of the operator community.

Responsibilities include creating technical and commercial solutions, delivering predictable outcomes, and maintaining talent in a tight

www.ogv.energy I September 2022

market. Strategic planning and multi-operator campaigns are high on the priority list – collaborating across the industry to deliver cost-effective solutions.

Perras states “Stena Wells is an extremely exciting prospect bringing something new to the market” –he also says “Stena Wells will be the only company offering a fully managed service for well construction in the North Sea and the second to provide full MODU well decommissioning”.

Stena Wells will work to deliver tier 1 integrated construction and decommissioning services and provide a complete cohesive package using Stena Drilling’s MODU fleet.

In times when operators are resource constrained Stena Wells aims to offer safe and predictable alternatives to the industry.

Erik Ronsberg – CEO of Stena Drilling, said “The addition of Mr Perras and his team to Stena Drilling provides a significant boost to our offerings both in Stena Drilling and Stena Wells.” Adding “Our current customers can leverage the teams’ technical capabilities in delivering wells around the globe – while

Stena Wells offers a complete service in both Well Construction and Decommissioning”.

The collaboration between Stena Drilling and Stena Wells creates an offering where customers receive not only the excellent services of a world-renowned drilling unit provider, but the well delivery experience of a world class engineering and execution team.

Mr Perras, a chartered engineer with IMechE, is currently a member of the Offshore Energy UK Well Decommissioning Group – co-leading the 2018 Well Decommissioning Guidelines Rev 6 – and a key member of the team delivering the current Rev 7 update.

DECOMMISSIONING Well-Safe taps Trendsetter for UK North Sea plug and abandonment campaign Trendsetter Engineering has secured a contract with Well-Safe Solutions to utilise its flagship intervention system and technical services for UK North Sea abandonment.

Under the contract, Trendsetter will deploy its Trident Intervention System which was designed for rapid reconfiguration in the field, providing the flexibility to conduct intervention riser, riserless wireline intervention and hydraulic stimulation operations all in one package.

The system will be deployed from the WellSafe Guardian rig to conduct a multi-well plug and abandonment (P&A) campaign for an estimated 320-day duration.

“We are excited to work with Well-Safe to bring Trident to the North Sea for plug and abandonment operations”, said Mike Cargol, VP of Rentals & Services for Trendsetter Engineering. “We look forward to providing our value-added intervention services and are eager to identify additional opportunities for collaboration for our two companies.”

Neil Ferguson, operations director at Well-Safe Solutions, stated: “Adding this capability to the Well-Safe Guardian unlocks considerable operational improvements and time savings for our clients during well intervention operations.”

Well-Safe bought the rig from Diamond Offshore back in 2019 and it was mobilised at the beginning of this year for its first job in the UK North Sea. Its first job included well decommissioning activities at the Hannay field under the company’s contract with Repsol Sinopec for the decommissioning of 14 subsea wells in the Hannay and Buchan fields.

Well-Safe was also awarded a contract by CNR International for the decommissioning of up to 14 wells on

the Banff and Kyle field located in the UK Central North Sea. The activities were scheduled to begin in early 2Q 2022, with Well-Safe Guardian undertaking the project.

Most recently, decommissioning services provider inked a new deal on the UK Continental Shelf (UKCS) with an undisclosed European operator to plug and abandon 14 wells.

The company said that this deal is the first scope agreed for the Well-Safe Defender semi-submersible rig, purchased in June 2022 from Awilco Drilling.

UKCS decommissioning cost estimate drops 25% to £44.5bn The cost of decommissioning oil and gas infrastructure has been cut by 25% in the past five years, according to the latest estimates published.

The North Sea Transition Authority’s (NSTA) Decommissioning Cost Estimate Report 2022 highlights industry’s ability to generate huge savings for the Exchequer and carry out projects in a more cost-effective manner.

The forecast fell £1.5bn (2%) to £44.5bn last year – contributing to a total cut of £15bn (25%) since 2017, when the NSTA introduced a baseline estimate of £59.7bn and set a target of reducing costs by 35% to £39bn by end-2022.

Decommissioning of offshore oil and gas installations is required by law but has long been an expensive and lengthy process. However, the introduction of the target coupled with industry’s ability to learn from experience, share lessons and execute projects more efficiently has been hugely effective.

The highly ambitious 35% target was always intended to be challenging and the significant savings already delivered greatly benefit companies, which can invest more in production and emissions reduction projects, and taxpayers by reducing the cost of decommissioning tax reliefs to the Exchequer.

Industry made swift progress in the first two years of the target, cutting the estimate by 17%, and while that has slowed, partly due to the logistical and economic pressures of the Covid-19 pandemic, progress has continued.

Importantly, the scale of reductions to the estimate is reflected in the final costs of completed projects, which are on average 20-25% lower than initially predicted, over the five years.

In 2021, decommissioning expenditure totalled £1.2bn, lower than the forecast £1.4bn, due to improved project execution and Covid-related deferrals of activity. This was a sizeable investment in the face of unprecedented logistical and economic pressures, and points to industry’s determination to carry out planned work and meet its decommissioning obligations.

Decommissioning spend is expected to ramp up to a peak of more than £2.5bn per year over the next two decades, offering a long-term opportunity for the supply chain to develop cost-efficient services and win more work overseas.

Improving performance on costs is likely to be challenging in the short term due to market inflation and competition for resources from other

DECOMMISSIONING SPONSORED BY

energy sectors. Therefore, the report calls on industry to redouble its efforts, ensuring that it plans effectively, collaborates on innovative commercial models, deploys new technologies and, where possible, reuses and repurposes infrastructure – all of which are priority areas in the NSTA Decommissioning Strategy. Repurposing infrastructure for energy transition projects, including carbon storage, can also make a significant contribution to the UK’s drive to net zero.

The NSTA is committed to supporting the sector and is encouraged that well decommissioning campaigns, which deliver better value and fewer emissions, have gained traction in the UKCS, as shown by recent, longer-term contract awards.

In addition, the NSTA is harnessing data and digital solutions, such as the NSTA’s Energy Pathfinder portal, Decommissioning Data Visibility pilot project and Suspended Wells application, to provide suppliers with a much clearer picture of upcoming work, giving them confidence to invest in skills and technologies.

Furthermore, as the 2017 target helped to sharpen industry’s focus on costs, the NSTA is providing fresh impetus by engaging with the sector to launch a new baseline estimate and cost efficiency target, effective from the start of 2023.

43

STATS & ANALYTICS PROVIDED BY

Field Development Update

Westwood Global Energy Group are specialist providers of detailed market intelligence for the offshore energy sector, covering; offshore rigs, production facilities, subsea equipment, subsea services, offshore marine and offshore renewables and power.

Offshore O&G-related engineering, procurement, and construction (EPC) contract awards announced over the last 30 days have been driven by a number of final investment decisions (FIDs), including Shell's Jackdaw gas field (UK), Aker BP's Trell & Trine (Norway), TotalEnergies' Begonia oil field and Azule Energy's Quiluma and Maboqueiro fields offshore Angola. During the period under review, 13 subsea tree unit contracts were recorded, bringing subsea tree awards year to date (YTD) to 158 units.

50 40

70.1 30

Finally in Australia, a total of six offshore wind zones have been identified by the Government, with the Bass Strait, located offshore Gippsland, entering the public consultation phase. Information about the public consultation procedures and the other five regions will be released in due course. The other five zones include two zones in the Pacific Ocean offshore the Hunter and offshore the Illawarra in New South Wales, the Southern Pacific Ocean region offshore Portland in Victoria, another zone in the Bass Strait offshore northern Tasmania and the final one is in the Indian Ocean region offshore Perth and Bunbury in Western Australia.

www.ogv.energy I September 2022

26.2 16.1

0 2019

2020

2021

2022

2023

Westwood’s 2022-23 outlook assumes a $65/bbl Brent oil price

Subsea Tree Awards #XTs 2022

158

2021

4

36

57

10

Sanctioned Firm

180

Pre-Order Probable

FPS Throughput Additions by Year of Sanction kpoepd 2500

LNG

Gas

Liquids

1500 1000 500 0 2019

2020

2021

2022

2023

Offshore O&G EPC Awards 2022-26 by E&P $billions to be awarded

121.5 39.7

21.4

17.9

11.6

11.2

10.8

9.7

9.2

9.0

8.6 Other

Dominating headlines was the launch of the Innovation and Targeted Oil and Gas (INTOG) offshore wind leasing round by Crown Estates Scotland. The auction will feature two streams, with the 'Innovation' stream awarding lease areas for up to 500MW worth of projects and the 'Targeted Oil and Gas’ stream awarding lease areas for up to 4GW worth of projects. The deadline for the submission of applications is 18 November 2022 and the winners of the auction are expected to be announced in March 2023.

41.9

10

Petrobras

The turbine OEM will supply a total of 14 SG 8.0-167 DD offshore wind turbines for the 112MW Ishikari Bay Port wind farm. The contract also includes a 15-year full-scope service agreement. According to Siemens Gamesa, the installation of the turbines is scheduled to commence in July 2023.

47.3

20

2000

Since the last update, Siemens Gamesa signed its first ever offshore turbine supply contract in Japan.

42.3

Saudi Aramco

Offshore Wind Update

60

Chevron

Finally, drillship demand continued to increase by two units to 75 rigs committed in July and marketed, committed utilisation reached 94%. Five drillships are available in the marketed fleet, while 16 remain cold stacked with no retirement recorded. Five new contracts, with a total of 3,315 drilling days, were signed in July with the average dayrate breaking the $400,000/day mark, last seen in December 2018.

Sanctioned

Shell

Global committed semisubmersible (semi) count dropped by one rig to 67 in July.

Another 15 units are available in the marketed fleet, while 15 are cold stacked with no retirement recorded. The marketed, committed utilisation was at 82% while total fleet utilisation was 69%. Six new fixtures, with a total of 728 drilling days, were recorded for the month. The longest fixture was awarded to Diamond Offshore’s Ocean Greatwhite for 300 days commencing in 1Q 2023 with BP in the UK.

Expected

70

QatarEnergy

The global committed jackup count increased by five rigs to 385 in July, leaving 47 marketed jackups available and another 58 jackups cold stacked. Marketed, committed utilisation increased to 89%, while total fleet committed utilisation went up to 79%. One new jackup was delivered; Saipem’s Perro Negro 11, while no jackups retired. There were eight new fixtures recorded in July, totalling 17,237 drilling days.

80

ExxonMobil

Offshore Rig Update

$billions

Woodside

Major EPC awards still anticipated in 3Q 2022 include a formal EPC award for Petrobras' P-82 FPSO unit destined for the Buzios development, as well as an award for BW Offshore's Polvo FPSO to be deployed on BW Energy's Maromba field offshore Brazil.

Shell is also expected to sanction the Gato do Mato FPSO, which will include 10 subsea trees, over 200 km of SURF, and 114 km of export pipeline.

Offshore O&G EPC Awards

Equinor

Recent EPC contract highlights include the engineering, procurement, construction and installation (EPCI) contract award to Sembcorp Marine for the platform topside to be installed on Shell's Crux development offshore Australia. Shell also awarded Aker Solutions the EPCI for a non-permanently manned fixed platform for its Jackdaw project in the UK Central North Sea. Offshore Angola, Saipem was awarded the EPC contract, including hook-up and commissioning assistance for the Quiluma wellhead platform (WHP). Following last month's reports that Keppel Shipyard was identified as the preferred bidder to build Petrobras' P-80 and P-82 floating production, storage, and offloading (FPSO) units to be deployed on its Buzios project, the Brazilian NOC has now confirmed the EPC award for the P-80 FPSO to Keppel. This award brings the number of floating production systems (FPS) contracted YTD to 10 units (five newbuilds, two conversions and three upgrades/redeployments). An additional 15 FPS units could be contracted before the end of 2022. However, supply chain inflationary pressure is expected to impact the contract award timeline for some of these planned units.

www.westwoodenergy.com

ENI

STATS & ANALYTICS

CNOOC

44

Offshore Energy Services Dashboard July / August 2022

Offshore Rigs available from

RigLogix

Global Rig CountBacklog Month-on-Month (Rig Years)

July Rig Counts Jackups

Jackups

Semisubs

58

14 54 15

19

Jackups

88 385

16

24

491

Semisubs

Drillships

15

58

47

5

97

Jackups

Semisubs

August 1

August 1

713.6

85

Drillships

Drillships August 1

116.9

18

96

Drillships

Semisubs

490

67

Available

Semisubs July 1 693 57

27

Stacked

96

97

75

Jackups Contracted

RigLogix

Drillships July 1 121.2

July151

89.2

63

344

Regional Month on Month Rig Counts (August vs July)

Jackups

1400 1200

June 1

1000 800

Arabian Gulf

South America

SE Asia

US GoM

NW Europe

Latin Arab Gulf America

Drillships -0.8

60%

May-21

Latin Arab Gulf America

50%

80% 75%

Total

Effective

Jul-20 Sep-20 Nov-20 Jan-21 Mar-21 May-21 Jul-21 Sep-21 Nov-21 Jan-22 Mar-22 May-22 Jul-22

90% 40% 85%

70% 65%

WindLogix

WindLogix

60% 55% 50%

12%

45%

17%

Awarded by 54% OEM (Rig Years) Backlog Month-on-Month

May-20 Jul-20 Sep-20 Nov-20 Jan-21 Mar-21 May-21 Jul-21 Sep-21 Nov-21 Jan-22 Mar-22 May-22

40%

21%

41%

Expected by Region

June 1

17% 89.0

120.4 26%

600 400 200 0 2019

2020

2021

May 1

687.0

2022

2023

Siemens Gamesa

Vestas

General Electric

Goldwind

Ming Yang May 1

Other

Arabian Gulf

SE Asia

Mar-21

Jan-21

Nov-20

Sep-20

US GOM

South America

NW Europe

SE Asia

Global

70%

US GoM

80%

Jul-20

90%

NW Europe May-20

Mar-20

Jan-20 Global

Jul-19

Sep-19

Jan-21

Mar-21

Nov-20

Sep-20

SE Asia

100%

Jul-20 Sep-20 Nov-20 Jan-21 Mar-21 May-21 Jul-21 Sep-21 Nov-21 Jan-22 Mar-22 May-22 Jul-22

May-20

US GOM

0.9

June 1

668.3

NW Europe

-0.5

May-20 Jul-20 Sep-20 Nov-20 Jan-21 Mar-21 May-21 Jul-21 Sep-21 Nov-21 Jan-22 Mar-22 May-22

Awarded

Jan-20

Nov-19

Sep-19

Jul-19

Jul-20 Sep-20 NW Europe Nov-20 Jan-21 Mar-21 US GoM May-21 Jul-21 SE Asia Sep-21 Nov-21 Jan-22 South America Mar-22 May-22 Jul-22 Arabian Gulf

Global

1600

May-20 Jul-20 Sep-20 Nov-20 Jan-21 Mar-21 May-21 Jul-21 Sep-21 Nov-21 Jan-22 Mar-22 May-22

1800

Expected

Global

0.6

60.00% 90% 90% -5.1 85% 85% 80% 80% 75% 75% 70% 70% Global NW US SE Latin Arab Gulf Global NW US SE Latin Arab Gulf 65% 65% Europe GOM Asia America Europe GOM Asia America 60% 60% 55% Global Rig Utilisation 55% 50% 50% Total Effective 45% 45% 90% 90% 40% 40% 85% 85% 80% 80% 75% 75% 70% 70% 65% 65% Offshore Wind available from 60% 60% 55% 55% Offshore WTG Awards (excl. Mainland China) 50% 50% #WTGs 4% 4% 45% 45% 4% 40% 40%

2000

Global

Arab Gulf

85.00% 2.1 80.00% 0.3 Global Rig Utilisation 75.00% -0.3 70.00% Semisubs 65.00% 60.00%

Nov-19

Latin America

Arabian Gulf

SE Asia

Arabian Gulf

SE Asia

US GOM

May-21 South America

-0.8

NW Europe

SE Asia

4.9

US GoM

Global

1.4 -0.6

-0.2

US GoM

Arab Gulf

NW Europe

Latin

Global

SE

Asia America 85.00% 80.00% 0.5 75.00% 70.00% -0.6 -1.4 Jackups65.00%-2.0

Arabian Gulf

US GOM

-0.1

South America

-0.9 South America

SE Asia

NW Europe

US GoM

Global

2.3

-1.5

NW Europe

Global

-0.8

Drillships

Regional Rig Count Month-on-Month (June vs May) 2.9

NW Europe Jul-20

2.0

0.8

Mar-20 Global

4.2

Semisubs

91.2

West Europe North America Asia May 1 Europe & FSU East

124.6 STATS & ANALYTICS SPONSORED BY

45

46

LEGAL & FINANCE

By Ken MacDonald, Partner, Brodies LLP

RESOLVING COMMERCIAL DISPUTES IN THE ENERGY SECTOR This year features as an important one for dispute professionals in the UK and further afield with Edinburgh hosting the largest international arbitration gathering in the world between 18 to 21 September. The International Council for Commercial Arbitration (ICCA), accredited as an NGO by the United Nations, is holding its bi-annual conference in the Scottish capital, a little over ten years after the installation of a modern regime for governing arbitrations in Scotland in the form of the Arbitration (Scotland) Act 2010 (which bears much similarity to the 1996 Arbitration Act for England & Wales).

Given the global reach of the energy sector, facing myriads of quickly evolving challenges and opportunities, across different geographies, arbitration is uniquely well placed to offer a neat solution to resolving disputes where a legally binding decision is required.

It comes without the associated baggage so often seen in running lengthy and costly court action. Arbitration avoids the dilemma of litigating in your counterparty's national courts (and breaks the deadlock on that issue in contract negotiations) by providing a neutral and internationally recognised safe haven for fair determination of disputes.

With virtually all steps being conducted without travel and by electronic communication, it reduces the carbon footprint in a way that resort to the courts simply cannot do. For this and the reasons explored in this article the sector should see increasing use of arbitration as the formal basis for resolution where negotiation and contract escalation procedures fail.

What is International Arbitration?

Arbitration has been likened to private sector litigation. It is the referral by disputants, most often companies who have entered into a contract with one another, to an independent decision maker who pronounces a legally binding decision. Rather than using the traditional court model to resolve commercial disputes, organisations can determine their own procedure and choose their decision maker. This often leads to quicker resolutions.

Finding effective ways to resolve disputes, with their inevitable burden on management time, is a worthwhile goal for any business.

Negotiation and mediation have their place as cost effective and quick means for overcoming differences but sometimes a formal, and enforceable, decision is required. That's where arbitration has a key role to play.

Why International Arbitration is growing in the energy sector Because it's not tied to the courts of any jurisdiction, international arbitration is geographically flexible. Businesses, wherever they are based, can agree the place of arbitration and the governing law most suitable to them.

www.ogv.energy I September 2022

Ken MacDonald

This can break deadlock in cross border disputes, ensuring that both parties have confidence in a neutral venue and are not stuck with the national courts of the other.

International arbitration offers real flexibility and choice with organisations picking the decision makers, the law, how and where hearings take place and the rules of engagement, tailoring the dispute to parties' needs rather than accepting inflexible rules.

This is ideal in the energy sector where bespoke creative solutions are required to meet complex and diverse needs.

Crucially, arbitrations are private. They are conducted behind closed doors with sensitive commercial information, such as financial data, customer lists, internal communications, policy and governance documents etc, are not subject to public scrutiny. Also, unlike court judgements, the scope to challenge arbitral awards is limited. This offers organisations finality and certainty with the confidence that they can obtain a final binding decision that allows them to move forward in their endeavours without the risk of being tied up in appeal for years.

Successful parties in arbitrations will also benefit from higher cost recoveries awarded to them than those achievable in litigation.

With over 140 nations signed up to the 1958 New York Convention making it easier to have your "win" recognised and enforced around the world.

Whilst litigation has an important role to play, not least in emergency applications to prevent a wrong (or the continuation of a wrong) from taking place, the benefits of international arbitration are clear. For the energy sector it offers an environmentallyfriendly and effective solution to managing cross-border relationships where resort to the public sector court system simply will not meet the needs and aspirations of those seeking quick, cost effective and private resolution of their disputes There is an increasing tendency for arbitrations to be used by business, particularly in cross border disputes. That direction of travel will only increase following the spotlight ICCA will provide in Edinburgh this year.

Brodies LLP is home to Scotland’s leading and largest dispute resolution and litigation team, with experts in international arbitration and all other aspects of dispute resolution.

Ken MacDonald leads Brodies' international arbitration practice.

Can you inspire the next generation of energy leaders?

If you’re a young professional working in the energy sector and you’re enthusiastic about the future of energy, then we want you to join our Energy Influencers!

www.myenergyfuture.co.uk

48

Tom Hultgren

COMPANY NEWS

Advisor Geology AGR

What is a geothermal reservoir static model?

THE KEY TO DELIVERING COMPREHENSIVE GEOTHERMAL RESERVOIR MODELLING

The static – or geological – 3D model is an integrated model containing the reservoir’s structural and property characteristics, expressed in a conglomerate of integrated sub-models.

The structural part comprises fault and fracture networks, geological formations, zones, segments and layering, and their specific attributes. The property part of the model includes various geological rock type ‘facies’ and expressions for their individual porosity, permeability, phase saturations, fracture intensity/density and aperture characteristics with specific attributes.

HOW GEOTHERMAL RESERVOIR MODELLING ESTABLISHES THE VIABILITY OF DRILL SITES? Given the level of investment required to get geothermal projects off the ground and see them through to completion, having a comprehensive and real-time view of a geothermal reservoir’s viability as early as possible is crucial.

But in the same way that the oil and gas industry deals with carbonate, basement and coalbed methane reservoirs, there are ways to model the subsurface approach to geothermal reservoirs – methods which allow us to better identify the projects presenting the biggest opportunities.

Reservoir modelling helps stakeholders build a robust business case, providing in-depth and live analysis of the drill site, its environmental makeup, how it might respond when work begins and, perhaps most importantly, its possibilities.

Expanding on the dynamic geothermal reservoir model

As experts in this rapidly growing space, we have set out our approach to geothermal reservoir modelling below, alongside some of the other established methods that are used to assess geothermal energy reservoirs.

Our approach to geothermal modelling There are a number of techniques deployed to model geothermal reservoirs. At AGR, we employ the 3D and 4D static (or geological) and dynamic (or simulation) models, characterising the reservoir’s structural and property aspects to give us a comprehensive geological description of the energy reservoir and its dynamic behaviour over time. Constructing such models is a multidisciplinary effort between the fields of geophysics, geology, petrophysics, reservoir engineering and reservoir modelling.

The modelling process includes gravimetric, magnetic, seismic data and well exploration and production data. These are analysed using both exploratory and confirmatory statistical methods and tools, often in labs.

www.ogv.energy I September 2022

Alongside this, uncertainty and sensitivity analyses are also conducted, producing several stochastic model realisations using Monte Carlo algorithms. The output could be uncertainty ranges – such as P10-P50-P90 volumetric figures – or Tornado diagrams, to understand which aspects of the reservoir are more or less critical. This analysis guides and supports decision-making processes relating to reservoir development and management.

The resulting 3D geothermal reservoir static model, with its various property sub-models for the matrix-fractures duality, is used as a starting point for the dynamic modelling process.

Needless to say, this insight is priceless to geothermal energy site developers and project stakeholders. Providing this level of understanding and confirming a reservoir’s commercial viability means geothermal energy developers can deliver successful projects and ultimately, bring sustainable geothermal energy sources onstream.

The reservoir models for geothermal energy studies typically have an architecture signified by an integrated matrix-fractures duality. The matrix part of the model defines the main energy storage rock volume with its vital components and characteristics, whereas the fractures element represents the connectivity network, or transportation ‘highway’ for energy, with its physical signatures.

Static volume calculations using reservoirspecific energy and formation variables are performed, producing numeric and graphic estimates for aspects such as gross, net, pore, saturated and in-place energy volume figures, given a specific model realisation.

To produce the dynamic geothermal reservoir model, we fit additional physical parameters to the static model, such as temperature and pressure fields, plus various dynamic aspects, financial guidelines, as well as constraints from reservoir engineering and production technology.

The latter could be various layouts for the well design – or altogether different means for stimulating the reservoir, such as ‘Fish Bone’ and ‘Manara’ technologies.

As touched on earlier, the intention of the dynamic model is to evaluate the reservoir’s dynamic behaviour over time, optimising reservoir development and management. Geothermal dynamic reservoir modelling helps to maximise production, ensure safety and unlock new efficiencies all while minimising cost, risk and environmental impact.

There’s more to it, though. The dynamic model can also incorporate a historical time series of production data, if available. Then, history match simulation results can be used in a feedback loop to update and fine tune the vital parameters of the static model. This approach also improves the accuracy of forecasts around future geothermal reservoir performance and geothermal energy production, with greater precision and reliability in the model predictions.

The static and dynamic geothermal reservoir models are also used for planning infill well drilling campaigns, to optimise energy drainage throughout the reservoir’s lifecycle.

Overview of alternative geothermal reservoir modelling approaches We’ve outlined our approach above, but various methods of geothermal reservoir modelling have emerged and evolved over the years. Different approaches are often combined and – depending on the unique characteristics of a given geothermal reservoir – these can be categorised as follows:

The Classic approach The Classic approach relies on the location of interpreted or modelled faults, combined with geological top and base reservoir surfaces. This may also include various internal zones and segments.

Parameters derived from these – such as Distance To Faults (DTF) and Distance To Unconformity (DTU) – are used to guide property modelling, laterally and vertically. The result would typically be four main types of ‘reservoir facies’, namely the Fault Core Zone (FCZ), Fault Damage Zone (FDZ), Pseudo-Matrix (PM) and Weathering Zone (WZ).

Establishment of the WZ may arrive from combining well data, DTU and interpretation of, for example, ‘low refraction’ seismic.

Typically, a matrix-fracture duality is established by this approach, where matrix and fracture properties are both dependent on the distance from the faults and top reservoir horizon. A Discrete Fracture Network (DFN), deterministic or stochastic, is established to express fracture properties like fracture intensity, fracture aperture, fracture porosity and fracture permeability.

The Seismic Inversion approach The Seismic Inversion method trains seismic data on well data to estimate reservoir properties.

Over the two decades, we have witnessed the development of methods for Artificial Neural Network-trained (ANN) porosity and permeability prediction cubes, to be used for model conditioning.

The idea is that the seismic cubes reflect varying mineralogy and a degree of weathering and fracture intensity in the geothermal reservoir.

The Geomorphology approach The Geomorphology method is based on modelling original mineralogy variations in the reservoir, combining this with the one or more paleotopographic shape characteristics of the reservoir formation surfaces. For example, this could be their profile and or plane-form curvature expressions. Peaks, deeps, valleys and ridges in a reservoir formation surface are assumed to reflect paleo landforms, which are then used to guide areas of enhanced, say, erosion and or weathering in valleys and depressions.

The Host Rock approach The Host Rock approach combines mineralogy, fracture intensity and weathering and or erosion characteristics of the reservoir rocks.

Criteria for, say, ‘weathering degree facies’ is established based on porosity and fracture intensity well logs, dividing the reservoir into segments and or zones classified by various degrees of weathering.

DTF and DTU metrics, surface vs. deep weathering and or erosion, in addition to anisotropy may also be included in this approach.

There are, then, a number of ways to approach geothermal reservoir modelling, each of which helps bring clarity, confidence and accurate information to project stakeholders – whether investors, operators or the wider supply chain.

With years of experience in the geothermal energy space, AGR is helping energy businesses navigate the complex geological, technological and commercial challenges they may encounter.

To learn more about our work in this area, please contact us. www.agr.com

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I’ve worked in the energy sector ever since I left college. I fell into the industry almost by accident when I was studying for a Business Admin MVQ at college. I was contacted by someone in the industry who needed some help with filing in an HR department for 6 weeks, at the end of the 6 weeks they decided to keep me on permanently while I finished by college course as an apprentice. So 6 weeks has quickly turned into 19 years in the industry!

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Over the next 10 years, what changes would you like to see in the energy sector with respect to D&I?

What does your job involve on an average day?

I’d say the main highlight for me has been finding a place to work where I’ve been able to develop and progress my career. Despite being here for so many years I’ve never felt stuck in a role and I have been constantly learning and taking on new challenges. This has allowed me to constantly keep myself engaged by working in multiple different departments, business units and new roles across the company.

What ambitions have you still got to fulfil professionally in your career?

I want to keep expanding my horizons and learning new skills. I don’t like to stay in one role for too long so once I feel I’ve hit a ceiling in terms of development and learning, I’m always on the look out for something else I can try my hand at.

As long as I’m evolving and learning new skills I’m completely happy in my work and looking forward to what I will achieve in the future.

Who has been the most influential person in your life professionally?

Naturally I’d like to see more women getting involved in energy and engineering as a whole.

Over the 19 years I’ve been in the industry it’s been very male dominant. As an industry we’re obviously making progress in diversifying talent across genders, ages and ethnicities, but there’s still definitely a lot more that can be done to make the industry more inclusive.

Given the experience you have now, what advice would you give a graduate just starting their career in the Energy sector?

The energy sector is in a transition period, and a lot of things have changed in the time since I started here. As an industry we’re striving towards net zero which certainly wasn’t as big a talking point when I began my career. So my advice would be to try innovate and come with new approaches to solve problems. Having a different viewpoint to people in the industry isn’t necessarily a bad thing and instead you could be a real driver for change.

If you were inviting guests to a dinner party, which 3 people would you invite and why?

Princess Diana – I have an obsession with the Royal family and I would love to speak to her to get her story on how it was to be a normal person thrown into a the life she ended up living.

Gordon Ramsey – As we need someone who would cook us a decent meal!

Lady Gaga – As every dinner party needs a Diva and I am sure she could belt out a few hits for us!

I would say the most influential person professionally was my first manager Elliott. He worked with me when Energy Resourcing was still called Primat. He’s a really knowledgeable person and he was equally approachable. I felt as though I could go to him with any problems I had and he really helped me get my feet under the table in the energy sector. In particular he helped me when I transitioned from dealing with staff to contractors as things became more fast-paced, anything related to CMS or HR he’d either know the answer or know where to get it.

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