OGV Energy Issue 74 by OGV Energy

NOV 2023 - ISSUE 74

DECOMMISSIONING

Wells expertise unlocking offshore decommissioning READ ON PAGE 4 u

GLOBAL ENERGY NEWS WORLD PROJECTS INTERNATIONAL GROWTH INNOVATION & TECH RENEWABLES CONTRACT AWARDS DECOMMISSIONING STATS & ANALYTICS LEGAL & FINANCE EVENTS

Decommissioning In this issue...

ELEMENTAL ENERGIES

P.04

LIBRESTREAM

P.30

LEYTON

P.36

EXCEED ENERGY

P.24

AGR

P.32

SWORD GROUP

P.37

STENA DRILLING

P.27

IMPULSE GROUP

P.33

CERULEAN

P.38

RE-GEN ROBOTICS

P.28

INTERVENTION RENTALS

P.35

AREG

P.39

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DECOMMISSIONING. IT’S ONLY THE BEGINNING. We offer everything you need to carry out offshore or onshore well plug and abandonment (P&A) safely and efficiently. But we’re much more than just a rig owner-operator - we offer market-leading subsurface basis of design (SSBoD) and well engineering expertise, backed by a global workforce with bases in the UK and Australia. Our technical studies and data-driven insight enable our integrated team to optimise barrier placement, whilst respecting isolation principles in oil, gas and condensate wells worldwide. We believe the subsurface is where effective well abandonment truly begins. And through effective collaboration with our clients, we think decommissioning is only the beginning of the transition towards net zero carbon emissions. What do you think?

MULTI-WELL, MULTI-OPERATOR CAMPAIGNS INTERNATIONAL PROJECT CAPABILITY FROM EUROPEAN AND ASIA-PACIFIC BASES SUBSURFACE BASIS OF DESIGN CCUS GEOTHERMAL ENGINEERING PACKAGES PEOPLE SERVICES STRATEGIC PLANNING P&A CLUBS

Well-Safe Solutions info@wellsafesolutions.com @wellsafesolutions +44 (0)1224 548 400 @wellsafe_decom

#wearewellsafe The Well-Safe Defender heading out to its first well decommissioning project, April 2023

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CONTENTS

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OGV COMMUNITY NEWS P.08 GLOBAL ENERGY NEWS P.10 4

WORLD PROJECTS MAP P.20

MONTHLY THEME P.22 OUR DIGITAL INDUSTRY P.36 RENEWABLES P.38 10

CONTRACT AWARDS P.40 DECOMMISSIONING P.42 STATS & ANALYTICS P.44 30

LEGAL & FINANCE P.46

EVENTS P.47

A WORD FROM OUR EDITOR Welcome to the November edition of ‘OGV Energy Magazine’ where we will be exploring the theme of Decommissioning’. A big thank you to our front cover partner Elemental Energies and you can hear from their ‘Head of Decommissioning’ - Julie Copland and her thoughts on the six steps that make a successful decommissioning project on pages 4-5 . We also have contributions from Exceed Energy, Well-Safe Solutions, Stena Wells, Drager, Impulse Group, AGR, Sword Group and very own digital business The OGV Studio. The rest of this month’s magazine as always provides you with a review of the Energy sector in the North Sea, Europe, Middle East, the US and Australasia along with industry analysis and project updates from Westwood Global Energy Group, the EIC and Renewables UK. Warm regards Dan Hyland Director

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

DECOMMISSIONING

Reducing Decommissioning Costs Through Early Wells Engagement The early resourcing of decommissioning projects with expert wells personnel is a key factor in reducing project costs, advocates industry expert Julie Copland. The head of decommissioning and low carbon at Elemental Energies, a leading global provider of wells-focused engineering, project management and consulting services, says engaging with expert wells teams during the earliest planning phases of well P&A and major decommissioning projects improves collaboration with subsurface teams. This in turn promotes a holistic approach to the early identification of risks, assessment of P&A technology solutions, and conceptual design. “Tackling the industry’s offshore decommissioning responsibilities is a vital stage of the energy transition. The global backlog of ageing assets presents a major, and high-cost challenge, so developing more efficient, lower-risk models to safely decommission assets is an essential step which must be taken quickly.

delivering activity on time and within budget,” adds Julie. With an extensive track record of successfully decommissioning 500 wells globally and having engineered the construction of more than 2000 wells, Elemental Energies is a significant hub of technical wells expertise. Committed to shaping wells-focused projects across the energy transition, Elemental Energies is building a world-leading offering to solve complex challenges in oil and gas, decommissioning, and the low carbon sectors of CCUS, and geothermal.

Five steps to achieving a successful decommissioning project Identifying the optimal solution early Wells teams are often only brought into a project once the subsurface team has completed its basis of design work. Engaging the wells teams early in the process allows for an open assessment of the widest range of wells and conveyancing approaches.

“Despite an acceleration of decommissioning projects, we have not yet seen a major shift in how projects are delivered. Teams continue to work in silos with subsurface, wells and other disciplines often working independently of each other. As the energy industry targets a 10% reduction in decommissioning costs by the end of 2028, a focus on performance and greater collaboration, underpinned by experience and agility is required,” says Julie.

The earlier the wells teams are involved the greater the opportunity there is to fully incorporate the optimal decommissioning solution into project planning, design, and contracting methodology. Over the longer term, this can save millions in lost time and project overrun.

A combination of regulatory tightening, balance sheet pressures and emissions reduction are driving decommissioning levels across an increasing number of jurisdictions. The North Sea and Gulf of Mexico are two of the most prolific offshore basins in the world, with the largest global share of offshore assets. In the UK there are around 470 offshore assets to be safely decommissioned over the next 30 years, with 10% of the wider North Sea assets now entering the decommissioning phase.

Taking a wells-centric approach to a project from the start allows wells and subsurface engineers to work in partnership. This enables experts to take a holistic approach to decommissioning and optimise planning efforts across the field abandonment and barrier strategies as well as well-specific approaches.

“With the majority of decommissioning risk sitting with the wells infrastructure, engaging the wells team as early in the project as possible can significantly reduce the potential for technical challenges and their associated costs. Taking a wells-centric approach to decommissioning not only eliminates many of the common problems associated with these complex projects but can also be a catalyst for

www.ogv.energy I November 2023

Integrating wells and subsurface teams can be transformational

Greater collaboration between wells and subsurface workflows, not only reduces project risks but also ensures the most cost-effective and efficient approaches are identified early on, far in advance of activity commencing.

Game-changing wells technology Wells activity is one of the most technologyfocused parts of a decommissioning campaign. Expert understanding of the status of game-changing technology in the wells space, and access to that information early in the planning process, can have a significant

impact on project efficiency. Putting this focus front and centre in the planning process allows a full assessment of the latest technology and options for new abandonment methods to be incorporated into the project.

Small optimisations create greater gains during well decommissioning Wells are the single largest cost and the most time-intensive part of a decommissioning campaign. Accounting for more than 50% of the project costs, small optimisations made during the wells decommissioning phase can have major time and cost implications. These optimisations can occur during planning, through close integration with other teams, such as subsurface, through the deployment of new technology, or through operational excellence during the execution phase. In addition, during the operational phase of well decommissioning, the optimisation of work instructions and the ability to respond swiftly to changes in well conditions are critical to ensuring time and cost targets are met. A trusted, independent decommissioning partner Finding a well engineering partner who is not only experienced at delivering complex decommissioning projects but also has the independence to ensure you receive the best advice and guidance on the most appropriate solutions for your project is critical. With a track record of successfully decommissioning more than 500 wells Elemental Energies has built the leading hub of well engineering talent within the energy industry with a major focus on supporting global decommissioning efforts. This includes leading experts and active projects across platform, subsea and wider facilities decommissioning, with a specific focus on the role P&A technology plays in transforming decommissioning performance. Committed to shaping the wells-focused projects, Elemental Energies is building a worldleading offering to solve complex challenges in oil and gas, decommissioning and the low carbon sectors of CCUS, and geothermal.

Find out more at elementalenergies.com

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Large scale platform P&A

We strive to be at the forefront of major platform decommissioning in the world’s biggest offshore markets. In collaboration with a key strategic partner, we are currently supporting a North Sea Operator to plan and deliver a large-scale platform decommissioning project to provide complete abandonment engineering and operational support across multiply platform wells over the next three years. The combined capability and experience is raising the bar for decommissioning projects of this scale.

Major subsea decommissioning

Wells P&A in subsea decommissioning routinely presents technical challenges. We are currently working with a major operator to perform preliminary engineering for one of the largest subsea decommissioning campaigns to be undertaken in the North Sea. The project scope includes a field level well integrity overview and preliminary assessment of P&A requirements for all wells. We are able to showcase the value of an expert-led, integrated wells and subsurface approach to field-wide decommissioning.

Integrated wells and facilities

Balancing activity between wells and facilities decommissioning requires expert project management.

Our teams are actively project managing an integrated wells and facilities decom project for a National Oil Company offshore UAE. Our scope encompasses all conceptual and detailed engineering, logistics management, mobilisations and inspection, detailed well and facilities decommissioning operations planning and operations execution using advanced plugging technology.

500

wells decommissioned

elementalenergies.com

2000+

wells engineered

650 +

project managed wells

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COMMUNITY NEWS

COMMUNITY news FIND ALL THE FULL COMMUNITY NEWS ARTICLES ON THE OGV ENERGY WEBSITE

J+S Subsea Limited secures significant contract with Harbour Energy Leading Subsea Controls Specialist, J+S Subsea Limited has signed a contract with Harbour Energy to deliver new subsea equipment into the Brodgar gas/condensate field worth more than £1 million. This new contract comes after a strong performance in the design and delivery of a new Subsea Control Module Mounting Base (SCMMB) for the Callanish F6 Xmas Tree (XT) back in early 2023. This new contract includes the design of a new Brodgar H4 Skid based Subsea Distribution Unit (SDU), a 400m in-field umbilical to connect the H5 XT, to the H4 Skid, and various interconnecting electrical and hydraulic jumpers to tie-in the subsea infrastructure.

Expro celebrates 50 years of North Sea oil, gas industry development This year, energy services provider Expro is celebrating its golden anniversary of supporting the North Sea energy industry and its highly successful 50-year connection with Great Yarmouth. Established at the height of the 1973 oil crisis, the company, originally called Exploration and Production Services (North Sea), was set up by John Trewhella OBE, Humphry Green and Jim Ross in a small office in the old Hudson House building in Battery Road, Great Yarmouth. The office, which was below the stairs, was known within the company as the ‘broom cupboard’. Success and expansion came quickly. Expro’s first job was on Christmas Eve 1973, testing an onshore well at the Wytch Farm development in Dorset.

www.ogv.energy I November 2023

OSSO announces new Saudi based partnership following 250% increase in Middle East revenue OSSO, the specialist fluid temperature control and separation solutions provider, announces a new partnership agreement with National Horizons Petroleum Services, a Saudi Arabia based distributor and service provider. Through this partnership, the companies will offer operators in Saudi Arabia direct access to OSSO’s comprehensive mud cooling services, supported by a local fleet of equipment and on-site rig assistance. The partnership follows substantial investments from OSSO to bolster its regional presence and service offering, including team expansion, a 150% increase in fleet size, and the introduction of land chillers to its mud cooling fleet - enabling it to provide a full turnkey service portfolio.

Montrose Port Authority embarks on bold restoration initiative for iconic Customs House and Granary Store The 19th Century listed buildings which previously reflected the importance of Montrose in the world of international trade and shipping have been bought by Montrose Port Authority (MPA). Situated on the Port’s north quayside, the imposing B-listed Customs House and Granary Store was previously owned by the Stonehaven-based engineering firm, Whittaker Group which planned to redevelop the almost derelict buildings into a modern office and training complex. Angus Council gave the project the planning permission in March this year. However, following a period of significant growth, MPA, which is a trust port, has bought the B-listed buildings and adjoining land to preserve it as an important piece of local maritime heritage with plans to also transform it into a commercially viable space and a vibrant community hub.

We all have a part to play for a sustainable future Every individual, organisation and region must play its part in shaping a sustainable future. Our story at ICR is not just about business growth; it's about embracing change, taking action and contributing to a world where sustainability is not an option but a necessity. We recently achieved our highest ever turnover figure, and I am immensely proud of what we have accomplished. However, our success is not measured solely in financial terms; it is also testament to our commitment to net zero goals. In our pursuit of decarbonisation, we've come to understand that incremental progress is just as vital as groundbreaking innovations. We believe in the power of marginal gains, and one of our strategies involves working with partners that share our proactive approach.

OEG Renewables strengthens position in survey market with GEOSIGHT deal Gamet in 2016, has established itself as a trusted provider of hydrographic and multi-sensor geophysical surveys, marine engineering, and dimensional control surveys, and boasts a team of skilled surveyors based from their head office in the historic cathedral city of Salisbury in Wiltshire, England. The acquisition of GEOSIGHT by OEGR marks an exciting milestone for both companies. By joining forces with group company Manor Renewable Energy (MRE) and an existing and well-respected survey team led by Alex Richards, OEGR aims to strengthen their survey and positioning offering in UK and overseas markets. GEOSIGHT will operate under the guidance of Brian Gamet as Managing Director, supported by Alex Richards as Operations Director and their newly combined team of dedicated survey professionals.

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Rosebank oil and gas field - ©Equinor

UK North

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Sea Energy Review By Tsvetana Paraskova

The long-awaited approval of the Rosebank oil project, falling emissions in oil and gas production, and opportunities for wells development were the highlights of the UK North Sea energy sector in the past month.

The North Sea Transition Authority granted at the end of September development and production consent for the Rosebank field, north-west of Shetland. The consent has been given by the oil and gas regulator to project owners Equinor and Ithaca Energy, following the acceptance of the Environmental Statement. “The FDP is awarded in accordance with our published guidance and taking net zero considerations into account throughout the project’s lifecycle,” an NSTA spokesperson said. Following the UK regulator’s consent, Equinor and Ithaca Energy took the final investment decision to progress Phase 1 of the Rosebank development on the UK Continental Shelf (UKCS), investing $3.8 billion. The Rosebank field, located around 130 kilometres north-west of Shetland in approximately 1,100 metres of water depth,

www.ogv.energy I November 2023

is estimated to contain total recoverable resources at around 300 million barrels of oil, with Phase 1 targeting estimated 245 million barrels of oil. According to Equinor’s plans, the field will be developed with subsea wells tied back to a redeployed Floating Production Storage and Offloading vessel (FPSO), with start-up planned in 2026-2027. Oil will be transported to refineries by shuttle tankers, while gas will be exported through the West of Shetland Pipeline system to mainland Scotland. TechnipFMC has been awarded an integrated engineering, procurement, construction and installation contract for subsea production systems, umbilicals, risers, and flowlines with an estimated value of around $500 million for the local content part. TechnipFMC has estimated that more than half of the contract value will be generated from local activities across the UK, with a large portion in Scotland. Odfjell Drilling has been awarded a rig contract at the field, with an estimated value of $328 million including integrated services, modifications, and options. The Deepsea Atlantic mobile rig is scheduled to start a seven-well drilling campaign in the second quarter of 2025, with four single well options included. The UK government welcomed the decision by regulators to approve the new Rosebank development. “While the government is scaling up homegrown clean energy sources such as offshore wind and nuclear, the UK still relies on oil and gas and this will continue to be the case over the coming decades,” the government said. “As the government takes forward a pragmatic, proportionate and realistic response to the path to net zero, a key part of this will be maintaining our domestic oil and gas industry which underpins our energy security and boosts the UK economy.” Energy Security Secretary Claire Coutinho said, “We will continue to back the UK’s oil and gas industry to underpin our energy security, grow our economy and help us deliver the transition to cheaper, cleaner energy.”

UK NORTH SEA REVIEW SPONSORED BY

Offshore Energies UK (OEUK), the leading trade body for the offshore energy sector, commented on the Rosebank approval that at its peak, the field could produce 69,000 barrels of oil per day – equivalent to 8 percent of the UK’s entire output between 2026 and 2030. Although the approval marks an important milestone in the UK’s energy reform, over its lifetime Rosebank will only meet eight months’ worth of UK demand, meaning more projects will be needed to manage reliance on imported oil and gas as UK production declines, OEUK says. “By promoting homegrown production, we avoid costlier, higher carbon imports while making more reliable supplies of energy in the UK, for the UK. We need more projects like Rosebank if we are serious about delivering a homegrown UK energy future,” OEUK chief executive David Whitehouse said. The approval and the FID on Rosebank in the West of Shetland basin could lead to more fields being approved, Wood Mackenzie said in a report. “As the biggest final investment decision (FID) in 20 years, Rosebank will account for 8% of UK liquids output at peak in 2027/28,” said Gail Anderson, Research Director for the North Sea. “Following this FID, there is more likelihood of other nearby fields such as Cambo progressing”. Environmental organisations criticised the approval of the Rosebank project. “This decision is nothing but carte blanche to fossil fuel companies to ruin the climate, punish bill payers, and siphon off obscene profits. But we already have the solutions to cut bills, increase energy security and cut emissions, but the government ignores them in favour of handouts to corporations at the expense of the rest of us,” said Philip Evans, Greenpeace UK’s climate campaigner. Friends of the Earth Scotland’s oil and gas campaigner Freya Aitchison commented: “The disgraceful decision to give Rosebank the green light shows the extent of the UK Government’s climate denial. Fossil fuels are driving both climate breakdown and the cost of living crisis yet the UK Government is slamming its foot down on the accelerator.”

UK ENERGY REVIEW

Scotland’s First Minister Humza Yousaf said he was “disappointed Rosebank has been given the goahead. We've raised concerns that the majority of what is extracted from Rosebank will go overseas, not remain in Scotland or the UK.” “We recognise the significant contribution the oil & gas sector makes to Scotland. However, our future is not in unlimited oil & gas extraction. It is in accelerating our just transition to renewables,” Yousaf added.

The sector has also halved flaring and venting and cut methane emissions by 45 percent compared to 2018, demonstrating the sector’s continuous commitment to decarbonisation, OEUK said. Most of the reductions in emissions so far have been made through operational improvements, process optimisation, and the decommissioning of older assets.

NSTA published its Wells Insight Report in October, which showed that only 48 development wells were drilled and 12 exploration and appraisal wells completed in 2022, compared to a NSTA baseline ambition of 60 development wells drilled per year to help slow the decline in production and assist in securing a greater proportion of domesticallyproduced hydrocarbons.

Without new investment in domestic oil and gas production, the UK’s carbon footprint will increase by 50 million tonnes of CO2e by 2050, because the country would become increasingly reliant on imported LNG, which is often produced and shipped to the UK from countries with less commitment to reducing the environmental impacts of production, the industry body noted.

The total in 2022 is down from the previous year in which 62 wells were completed. However, the total development well spend of £1.23 billion was only slightly less than the £1.33 billion in 2021, indicating that average wellbore cost in the UKCS has risen, NSTA said.

The sector needs support from regulators and government to enable grid access for electrification of projects so that emissions could be cut further.

The regulator warned that the decline in well activity could affect assets’ production, with fields approaching a cessation of production (CoP) tipping point.

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“Collective action is required to unlock investment in highly complex projects such as the electrification of production facilities and other approaches that are new to the UK. Industry cannot do this alone,” OEUK sustainability and policy director Michael Tholen wrote in the foreword to the report.

Still, NSTA sees some encouraging signs—last year In company news, Subsea7 announced at the end saw a reduction in shut-in wells from 785 to 743, of September that Subsea Integration Alliance a 5-percent reduction in shut-in well stock, signed a memorandum of understanding as operators focused on intervention (MoU) aimed at forming a framework “Together we to restore production from idle wells can safely deliver agreement with bp for integrated reacting to increased commodity projects with improved subsea developments. prices and the need to secure project schedules, domestic supply. “The members of Subsea Integration reducing our total cost of

Alliance have been a key supplier of ownership and harnessing Activity may pick-up in the near synergies through a bp for decades, and by combining future—operators forecast with collaborative oneour resources and knowledge, we high and moderate confidence that team mindset.” 77 exploration and appraisal (E&A) can bring significant benefits to our wells will be drilled between 2023 and customers and our stakeholders,” said 2025. A total of 12 of these 77 wells are Ewan Drummond, bp’s SVP Projects. forecast in 2023, 17 in 2024, and the remainder in “Together we can safely deliver projects with 2025. As many as 34 wells are in the Central North Sea, 15 in the Southern North Sea/Irish Sea, 13 in the improved project schedules, reducing our total cost Northern North Sea/West of Shetland. of ownership and harnessing synergies through a collaborative one-team mindset.” “We are committed to helping ensure UK energy security and well interventions which increase production from existing facilities can play a key role in that. Production from existing facilities can also have a lower carbon footprint,” said Andy Brooks, NSTA Director of New Ventures. “It is also vitally important that we increase development drilling in order to sustain domestic supply, and we are encouraged by the forecast pickup on Exploration and Appraisal activity in the next few years.” In the Emissions Report 2023 published in October, OEUK estimates that emissions from the production, transport, and processing of oil and gas in the UK fell to the equivalent of 14.28 million tonnes of CO2 in 2022, down by 24 percent compared with the 2018 figure of 18.9 million tonnes.

Petrofac, a provider of services to the energy industry, has been awarded a three-year contract extension in support of Repsol Sinopec Resources UK’s North Sea operations worth more than US$100 million. The award is for the provision of operations and maintenance services, supporting more than 300 jobs across a range of assets, including Arbroath, Auk, Bleo Holm, Claymore, Clyde, Fulmar, Montrose, Piper, Saltire and Tartan assets in the North Sea. Petrofac also provides support to Flotta Oil Terminal and Nigg Oil Terminal. Diamond Offshore has announced that the Ocean Patriot started its two-well P&A campaign with Repsol in the UK North Sea—the first time the company has worked with Repsol in the North Sea. 

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Europe Energy Review

By Tsvetana Paraskova

Oil & Gas

Updates on oil and gas projects and drilling plans offshore Norway, the UK’s updated net-zero strategy, and numerous plans for wind, solar, hydrogen, and wave energy capacity additions across Britain and Europe featured in the European energy sector in the past weeks.

Equinor and its partners in the Johan Castberg project issued an updated cost development analysis, saying that the investment estimate had increased by nearly $1.2 billion, or NOK 13 billion, since last year. The plan for start-up of the Johan Castberg oilfield in a new oil province in the Barents Sea remains unchanged for the fourth quarter of 2024, the Norwegian energy major said. Proven volumes in Johan Castberg are estimated at between 450 and 650 million barrels of oil. The vessel is designed for a daily production of close to 190,000 barrels. Despite the cost increases in the years since the development plan was submitted in 2017, “Johan Castberg is still a good project with a solid economy,” said Geir Tungesvik, Equinor’s executive vice president for Projects, Drilling & Procurement. Equinor has also signed a new long-term gas sales agreement with Austria’s energy company OMV for five years starting 1 October 2023 and with an annual volume of 12 TWh. The gas will be delivered at Germany’s virtual trading hub THE (Trading Hub Europe) for the OMV European portfolio. The Norwegian authorities have granted consent for start-up of the Tommeliten A field in the North Sea, operated by Conoco Phillips.

www.ogv.energy I November 2023

The operator estimates that around 24 million standard cubic metres (150 million barrels) of oil equivalent can be recovered from Tommeliten A. Neptune Energy announced in early October the start of drilling on the Ofelia appraisal well in the Norwegian sector of the North Sea. The Ofelia discovery (PL 929) was made in August 2022 and is located approximately 14 kilometres north of the Neptune-operated Gjøa field. Preliminary estimates of recoverable volumes at Ofelia are in the range of 2.5-6.2 million standard cubic metres or 16-39 million barrels of oil equivalents. Aker BP has awarded Multiconsult Norge AS a contract for civil engineering, consultancy, and supervision services in the Yggdrasil power from shore project. The power from shore system will provide a stable and secure power supply to Yggdrasil, with low emissions. On 31 March, the Ministry of Petroleum and Energy awarded Aker BP a licence to connect the platforms in the Yggdrasil area to the power grid in Samnanger in Vestland County. The European Commission has approved, under EU State aid rules, a 106-million-euro Greek measure to support the completion of the construction of the LNG terminal in Alexandroupolis, as it would help the diversification of energy supplies and cut dependence on Russian fossil fuels.

EUROPE ENERGY REVIEW Low-Carbon Energy

BayWa r.e. has received consent for its planning application to develop one of its biggest stand-alone battery energy storage system (BESS) in Europe and its first in the UK in partnership with Grüne Energien Solar GmbH. The 57 MW BESS facility “Meadow Farm” has a capacity of up to 171 MWh and will be built in Stockton-on-Tees in Northeast England.

UK Prime Minister Rishi Sunak announced at the end of September a new approach to Net Zero, which softened some of the key policies, including a delay of a ban on the sale of new gasoline and diesel passenger cars—from 2030 to 2035. UK renewable energy associations have expressed concern that the shift in policies could further damage the UK’s competitiveness in attracting investments in green technologies. Offshore Energies UK (OEUK) noted that the UK homegrown energy and pragmatic policies are necessary to safeguard energy security and the homegrown jobs and supply chains needed to build the low carbon future in the UK. “We know this sector can and must be a big part of the answer to the challenges the country faces on the cost of living, energy security, economic growth and tackling climate change,” said Mike Tholen, OEUK sustainability and policy director. RenewableUK’s Chief Executive Dan McGrail said that the PM needs to restore investor confidence in green technologies in the UK and “The fact is that the speeding up the transition to a green economy is the only way to protect billpayers from price shocks.” In other clean energy policies, The Crown Estate has set out further details on its plans for Offshore Wind Leasing Round 5, which aims to establish new floating offshore wind technology off the coast of Wales and South West England. Round 5 is expected to be the first phase of development in the Celtic Sea. The UK and Germany signed at the end of September an agreement to help accelerate the development of an international hydrogen industry. Commenting on the agreement, OEUK said that it represents a great boost to UK’s homegrown energy. “The energy resources in the waters around the UK give us a great foundation, with significant hydrogen potential, Europe’s largest offshore carbon storage potential, enough oil and gas resources to supply over half the country’s needs and the world’s second largest offshore wind capacity,” said OEUK Head of Energy Policy Enrique Cornejo. In company and project news, the world’s largest offshore wind farm, Dogger Bank, started producing electricity for the first time for British homes and businesses in early October. The 3.6 GW Dogger Bank Wind Farm is being constructed in UK waters 70 nautical

Adam Morrison, Ocean Winds’ Country Manager for UK.

“With the ongoing construction of Moray West and the development of the Caledonia project, Ocean Winds is multiplying the capacity of the Moray Firth region to generate close to 4 GW of clean energy from offshore wind and unlocking key opportunities for supply chain and local communities”,

miles (130 km) off the coast of Yorkshire and in three 1.2GW phases known as Dogger Bank A, B, and C. When fully complete, Dogger Bank’s capacity will comprise 277 giant offshore turbines capable of producing enough clean energy to power the equivalent of six million homes annually and deliver yearly CO2 savings equivalent to removing 1.5 million cars from the road. The Offshore Renewable Energy Catapult’s Floating Offshore Wind Centre of Excellence (FOW CoE) has launched its fourth key strategic programme focused on reducing risk and costs associated with floating offshore wind, and supporting supply chain growth in construction, operations, and maintenance. The West of Orkney Windfarm has reached a major milestone by submitting comprehensive offshore consent applications to Scottish Ministers for a proposed offshore windfarm. The project – developed by a joint venture of Corio Generation, TotalEnergies, and Renewable Infrastructure Development Group (RIDG) – will have up to 125 turbines on fixed foundations, an expected capacity of around 2 GW, and aims to deliver first power in 2029. Associated British Ports has announced a deal to investigate an area for the development of infrastructure to support offshore wind manufacturing, assembly, and marshalling and green energy on the Cromarty Firth in Scotland, within the Inverness and Cromarty Firth Green Freeport. RWE and npower Business Solutions have signed a Memorandum of Understanding to market green power to corporate customers in the UK. The aim is to offer nBS’s customers power purchase agreements (PPAs) from RWE’s renewable energy generation portfolio.

Marubeni Corporation has signed a Memorandum of Understanding with the UK Department for Business and Trade, on comprehensive cooperation in clean energy projects, including offshore wind and green hydrogen businesses. The UK Government affirmed its commitment to support Marubeni’s plans, with its partners, to invest approximately £10 billion in clean energy projects over the next 10 years. Ocean Winds announced in early October the sale of a 16.6% stake of its majority stake in its operating Moray East Offshore Wind Farm, to international infrastructure investor Equitix. “With the ongoing construction of Moray West and the development of the Caledonia project, Ocean Winds is multiplying the capacity of the Moray Firth region to generate close to 4 GW of clean energy from offshore wind and unlocking key opportunities for supply chain and local communities”, said Adam Morrison, Ocean Winds’ Country Manager for UK. Ocean Winds also announced its joint participation – together with Banque des Territoires – in the AO7 South Atlantic tender in France, featuring 1 GW bottom fixed capacity. In Ireland, Simply Blue Group, a leading blue economy developer, and Ireland’s energy company ESB have announced that they are pooling expertise and resources to deliver a 5 MW wave farm array, next to the Co Clare coast. Known as Saoirse and developed by Simply Blue Group, the wave energy demonstration project aims to prove the viability of wave energy in Irish seas. Hystar AS announced in early October a fully automated 4 GW electrolyser factory in Høvik, just west of Oslo in Norway, which will be delivered in 2025, with construction commencing in early 2024. “Our Høvik GW factory demonstrates our commitment to rapidly expanding our European operations and meeting the strong demand for our technology across Europe,” Hystar CEO Fredrik Mowill said. Battolyser Systems has signed a 40-millioneuro financing agreement with the European Investment Bank (EIB), aimed at commercialising and scaling production capacity of its Battolyser product range. The financing will enable the company to scale its production facility in Rotterdam towards mass production of its combined electricity storage and electrolyser stack system. “With the Battolyser, excess energy can be stored or converted into green hydrogen, thus reducing what is called the cost of ‘missed energy’ in our grid,” EIB Vice-President Kris Peeters said. 

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USA Energy Review By Tsvetana Paraskova

E&P Business Activity Grows But Costs Continue To Rise

US oil and gas activity grew modestly in the third quarter as cost increases continued for an 11th consecutive quarter, while the main oil lobby continued to call for consistent federal leasing regulations for the industry to meet America’s energy needs. Meanwhile, supermajor ExxonMobil announced a merger with Pioneer Natural Resources in an all-stock transaction to create a giant Permian producer.

Business activity in the Eleventh Federal Reserve District – comprising the large oil and gas producing states of Texas, northern Louisiana, and southern New Mexico – rose in the third quarter, according to oil and gas executives responding to the latest Dallas Fed Energy Survey for Q3. The broadest measure of conditions for energy firms in the Eleventh District, the business activity index, increased from 0 in the second quarter to 10.9 in the third quarter, thanks to exploration and production where the index jumped from 1.0 in the second quarter to 22.5 in the third quarter. However, the business activity index for oil and gas support services firms declined from -1.9 to -12.2, the survey showed. As a result of higher business activity in the E&P sector, oil and natural gas production increased at a faster pace in the third quarter compared with the second quarter, according to executives at E&P firms. The oil production index increased to 26.5 in the third quarter from 8.0 in the second quarter, and the natural gas production index rose to 15.4 from 2.1. Firms in Texas, New Mexico, and Louisiana reported an increase in costs for an 11th quarter in a row, according to the survey. The outlook improved, with the outlook index moving into positive territory in the third quarter, jumping from -9.1 to 36.0. Optimism was more pronounced among E&P firms; the outlook index was 46.8 for E&P firms

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compared with 14.9 for services firms. The overall outlook uncertainty index remained positive but plunged 30 points to 6.8, suggesting that while uncertainty continued to increase on net, fewer firms noted a rise in the recent quarter. On average, respondents expect a West Texas Intermediate (WTI) oil price of $88 per barrel at year-end 2023, with responses ranging from $70 to $120 per barrel. Survey participants expect a Henry Hub natural gas price of $3.14 per million British thermal units (MMBtu) at year-end. For reference, WTI spot prices averaged $90.29 per barrel during the survey collection period, and Henry Hub spot prices averaged $2.68 per MMBtu. Responding to several special questions, most executives, 84 percent, said they expect the number of US oil rigs six months from now to be near current levels. Fourteen percent note they anticipate the number of US oil rigs drilling six months from now to be much higher, while only 1 percent of executives said they expect it to be much lower. A higher percentage of executives at support service firms expects the number of US oil rigs to be much higher in six months compared with the percentage of E&P executives who agree. Looking to 2024, across E&P firms, 60 percent of executives expect drilling and completion costs per well in 2024 to be higher than in 2023, while 18 percent expect costs to be lower. Twenty-one percent expect no change. Executives from small E&P firms were more likely to expect an increase in costs per well than those from large E&P firms.

USA ENERGY REVIEW

In comments to the questions, one executive at a support services firm said,

Average oil and natural gas industry employment supported by Gulf of Mexico activities would fall by 13 percent to just under 310,000 jobs nationally, while industry investment in the US Gulf of Mexico is expected to drop by 14 percent in the period 2023-2040.

“The risk to our industry is in the outlook. If the outlook remains murky, or negative, it becomes a major headwind for hiring, financing, wealth generation, etc.” Other executives commented on the US Administration’s policies that slow down exploration and hence, production, saying that the regulatory environment continues to be challenging. “Increased regulation is affecting our business. In a business full of uncertainty, one thing is certain, and that is the administration wants to destroy the American oil and gas independent producer,” an executive at an E&P firm said. “Uncertainty due to the attack on the oil and gas industry by the administration is an issue affecting our business. The country cannot get to green without oil and gas for many years into the future,” another executive noted.

API Vice President of Upstream Policy Holly Hopkins.

“At a time when offshore production in nations around the world is needed, this proposal could increase reliance on foreign regimes for our energy and may compromise U.S. energy security,”

API Calls For Revision of Rules That Stifle Domestic Energy Supply

Therefore, the associations “urged BLM to revise the proposed rulemaking to ensure the American people can continue to reap the economic, energy security and environmental benefits of continued domestic energy production,” API said in a statement. “If implemented as written, the Proposed Rule could essentially eliminate the opportunity for exploration or the expansion of newly discovered producing areas, constrain future oil and natural gas development to areas where it already exists, and shrink such areas even further, thereby discouraging further innovation, new discoveries, and ultimately domestic production,” the associations said in the comments.

“At a time when offshore production in nations around the world is needed, this proposal could increase reliance on foreign regimes for our energy and may compromise U.S. energy security,” said API Vice President of Upstream Policy Holly Hopkins. API has also recently criticised the Biden Administration’s long-delayed release of the final five-year programme for federal offshore leasing.

“The Proposed Final Program, which represents the smallest number of oil and gas lease sales in history, sets a course for the Department to support the growing offshore wind industry and protect against the potential for environmental damage and adverse impacts to coastal communities,” said Secretary of the Interior Deb Haaland.

“Bottom line, inflation pressures are not abating and are far from transitory,” the executive added.

In comments submitted at the end of September to the Department of the Interior’s Bureau of Land Management (BLM), the associations raised concerns that the proposed rule overreaches BLM’s statutory authority, disregards Congress’s intent to preserve federal leasing programs, and rejects existing robust planning and environmental review processes, allowing BLM to constrain onshore energy development on a case-bycase basis.

Moreover, government revenue from oil and natural gas production is expected to fall by 22 percent to $5.7 billion annually.

At the end of September, the US Interior Department announced the fewest offshore oil and gas lease sales in history in its proposed final programme for 2024–2029.

At services firms, one executive said that “Rising interest rates are negatively impacting available free cash flow to deploy to heavy equipment capital expenditures.”

The American Petroleum Institute (API) has joined with 13 energy trade associations in calling on the Biden Administration to prioritise US energy needs by developing fair and consistent federal leasing regulations.

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API President and CEO Mike Sommers

API President and CEO Mike Sommers commented on the proposed programme,

“For decades, we’ve strived for energy security and this administration keeps trying to give it away.”

“This restrictive offshore leasing program is the latest tactic in a coordinated strategy to reduce energy production, ultimately weakening America’s energy dominance, limiting consumers access to affordable reliable energy and compromising our ability to lead on the global stage.”

API also released in early October a new analysis that outlines the potential consequences of new vessel restrictions on American oil and gas workers in the US Gulf of Mexico. The study, conducted by EIAP, finds that recently proposed restrictions on oil and natural gas vessels operating in the US Gulf of Mexico would have a major impact on jobs, industry investment, government revenue, and oil and natural gas production in the region, leading to a nearly one-quarter decline – which is more than 500,000 barrels of oil equivalent per day – in energy production in the Gulf of Mexico by 2040 even as demand continues to rise. If the vessel restrictions are implemented, average oil and natural gas production is set to decline to just under 2 million barrels of oil equivalent per day, a 24-percent reduction from projected levels, between 2023 and 2040, according to the study.

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“For decades, we’ve strived for energy security and this administration keeps trying to give it away.”

Exxon-Pioneer Tie-Up In early October, Exxon Mobil Corporation and Pioneer Natural Resources jointly announced a definitive agreement for ExxonMobil to acquire Pioneer, in one of the biggest oil industry transactions in recent years that will create a Permian giant. The merger is an all-stock transaction valued at $59.5 billion, or $253 per share, based on ExxonMobil’s closing price on October 5, 2023. The merger combines Pioneer’s more than 850,000 net acres in the Midland Basin with ExxonMobil’s 570,000 net acres in the Delaware and Midland Basins, creating the industry’s leading high-quality undeveloped U.S. unconventional inventory position. Together, the companies will have an estimated 16 billion barrels of oil equivalent resource in the Permian. 

HEADER ENERGY REVIEW GLOBAL Photo creidt: Reuters

MIDDLE EAST Energy Review By Tsvetana Paraskova

Saudi Arabia affirmed its voluntary oil production cut would be in place until the end of 2023, OPEC raised significantly its long-term oil demand estimate, while the Hamas attack on Israel in early October brought the Middle East tensions to the spotlight and the war premium back to the oil and gas markets.

Saudi Arabia Continues To Work for ‘Balanced’ Oil Market Saudi Arabia said on 4 October that it would continue cutting an extra 1 million barrels per day (bpd) from its oil production in November and December, while Russia said in a separate statement it would continue to reduce oil exports by 300,000 bpd until the end of the year. Saudi Arabia’s crude oil production will be around 9 million bpd until the end of the year, as the Kingdom continues to work for “stability and balance on the oil markets,” it said. “This voluntary cut decision will be reviewed next month to consider deepening the cut or increasing production,” Saudi Arabia said. At the same time, its key partner in the OPEC+ agreement, Russia, said that Moscow would continue with its 300,000-bpd cut to oil exports by the end of the year. At their October meeting hours after the Saudi and Russian announcements, the Joint Ministerial Monitoring Committee (JMMC) of OPEC+ made no changes to the alliance’s output policy and acknowledged the supply cuts from Saudi Arabia and Russia.

Hamas Attack on Israel Rekindles Tensions in the Middle East The market had only a few days to digest the news that OPEC+ is sticking to its guns and

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doesn’t plan to change its production policy, for now. Early on October 7, Hamas attacked Israel from the Gaza Strip and the relative calmness that had settled in the Middle East in recent months ended. While analysts initially said the chances of a wider conflict and disruption to oil and gas supply were low, they haven’t ruled out the involvement of other countries in the Middle East in a wider conflict. Analysts are also closely watching whether the attacks would result in more severe sanctions against Iran, which has managed in recent months to significantly increase its oil production and exports – mostly to China.

OPEC Hikes Long-Term Demand Outlook OPEC issued an upbeat forecast of global oil demand through 2045 in its 2023 World Oil Outlook, raising its demand projection by a massive 6 million bpd in 2045 compared to last year’s estimate. OPEC now expects global oil demand to rise by more than 16 million bpd between 2022 and 2045, rising from 99.6 million bpd in 2022 to 116 million bpd in 2045. India will be the largest driver of growth through 2045, expected to add 6.6 million bpd to oil demand over the period. Other Asia’s oil demand is set to increase by 4.6 million bpd, China’s by 4 million bpd, Africa’s by 3.8 million bpd, and the Middle East’s by 3.6 million bpd, according to OPEC.

MIDDLE EAST ENERGY REVIEW

“Recent developments have led the OPEC team to reassess just what each energy can deliver, with a focus on pragmatic and realistic options and solutions. In this regard, our Reference Case sees oil demand reaching 116 million barrels a day (mb/d) by 2045, around 6 mb/d higher than in the WOO 2022, and with the potential to be even higher,” OPEC Secretary General Haitham Al Ghais wrote in the foreword to the report. OPEC also sees continued investments in oil and gas as crucial for market stability and said in its annual outlook that the world needs $14 trillion in cumulative investments in the oil sector by 2045 to avoid energy and economic chaos. “Calls to stop investments in new oil projects are misguided and could lead to energy and economic chaos,” Al Ghais said. “History is replete with numerous examples of turmoil that should serve as a warning for what occurs when policymakers fail to acknowledge energy’s interwoven complexities,” the head of OPEC warned.

The Middle East Could Be Crucial To New Global Gas Supply Despite the surge in renewable energy installations, natural gas output from currently producing fields will not be enough to meet projected demand, Rystad Energy said in an analysis in early October. Gasrich geographies such as the Middle East, with basins such as Rub al Khali, will play an essential role in bridging that gap, providing an estimated 20 million tons per annum (tpa) of LNG by 2040, according to the independent energy research firm. “With reduced emissions and regional energy security goals aligned, gas is poised to play a pivotal role in the global energy transition,” said Aatisha Mahajan, vice president of exploration, Rystad Energy. “The Middle East is a key driver of this shift, slowly moving into developing and increasing gas volumes as part of their new energy transition strategies.”

Middle East Oil & Gas Majors Sign Milestone Deals The top national oil and gas companies in the Middle East – Saudi Aramco, QatarEnergy, and ADNOC – have recently signed major deals in gas, oil, refining, carbon capture, and emissions reductions.

business. The strategic partnership with MidOcean Energy marks Aramco’s first international investment in LNG. Under the deal, which is subject to regulatory approvals, Aramco has the option to increase its shareholding and associated rights in MidOcean Energy in the future. The Saudi oil firm also said it was further advancing the development of emissions reduction solutions including lower-carbon hydrogen, Direct Air Capture (DAC) of carbon dioxide, a novel approach to CO2 storage that involves turning carbon dioxide into stone, and the harnessing of geothermal energy. The projects support Aramco’s ambition to achieve net-zero Scope 1 and Scope 2 greenhouse gas emissions across its whollyowned and operated assets by 2050, as well as Saudi Arabia’s 2060 net-zero ambition. In Qatar, QatarEnergy and Chevron Phillips Chemical Company LLC (CPChem) announced on 9 October they had secured $4.4 billion financing for the Ras Laffan Petrochemicals project, a world-scale integrated polymers complex in Ras Laffan Industrial City, Qatar. QatarEnergy has also signed two long-term LNG sale and purchase agreements with TotalEnergies for the supply of up to 3.5 million tons per annum (MTPA) of LNG from Qatar to France. Under the deals, LNG will be delivered ex-ship to the Fos Cavaou LNG receiving terminal in southern France, with deliveries expected to start in 2026 and last for 27 years. Worley said at the end of September they would be providing front-end engineering design (FEED) services for QatarEnergy LNG's CO2 sequestration project in Ras Laffan, Qatar. Worley will develop the FEED study and engineering, procurement and construction (EPC) scope of work and the project is set for completion in 2024. Once completed, the sequestration facility will be capable of capturing 4.3 million tonnes of CO2 every year.

by 2030. As part of this strategy, ADNOC has recently announced the final investment decision (FID) to develop its pioneering 1.5 mtpa Habshan carbon capture, utilization and storage (CCUS) project. Petrofac has been awarded an Engineering, Procurement and Construction (EPC) contract by ADNOC Gas for the Habshan CCUS project, one of the largest carbon capture projects in the Middle East and North Africa region. ADNOC and U.S. Occidental have announced an agreement to undertake a joint preliminary engineering study for the construction of a direct air capture (DAC) in the UAE, which would be the first megaton-scale facility outside the United States. The study will assess the proposed one million mtpa DAC facility to be connected to ADNOC’s carbon dioxide infrastructure for injection and permanent storage into saline reservoirs not used for oil and gas production. ADNOC plans to trial the use of repurposed electric vehicle batteries to decarbonise its remote production operations and reduce costs. The pilot, run in partnership with German start-up Power I.D., will see EV batteries deployed that would have otherwise been disposed of and assembled into a largescale Battery Energy Storage System. In a landmark agreement, ADNOC announced in early October the final investment decision and award of contracts for the Hail and Ghasha Offshore Development project, which is planned to operate with net zero CO2 emissions—the first such project in the world. The Hail and Ghasha development design is expected to capture 1.5 million tonnes per year (mtpa) of CO2 which will be captured, transported onshore, and safely stored underground, while low-carbon hydrogen is produced that can replace fuel gas and further reduce emissions. The project will also use clean power from nuclear and renewable sources from the grid. 

In the United Arab Emirates, ADNOC has updated its carbon management strategy and its ambition to double its carbon capture capacity to 10 million tonnes per annum (mtpa) of c a r b o n dioxide

Saudi oil giant Aramco is entering the global LNG business by signing definitive agreements to buy a strategic minority stake in MidOcean Energy for $500 million. MidOcean Energy, formed and managed by EIG, an institutional investor in the global energy and infrastructure sectors, is currently in the process of acquiring interests in four Australian LNG projects, with a growth strategy to create a diversified global LNG Ghasha development: Artificial islands at a key Adnoc offshore field Photo: ADNOC

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OVER THE YEARS Brent Oil Column November 2023

YEAR AGO

1 Year Ago - $85.59 European refineries found themselves oversupplied with crude as an expected shortage owing to a looming EU ban on Russian oil was yet to materialise. The spread between front-month Brent crude futures significantly reduced, with concerns regarding the EU embargo on Russian crude beginning to diminish.

YEARS AGO

Crude oil prices experienced a significant decline, reaching levels that hadn’t been seen in nearly a year as traders anticipated an oversupply of oil coinciding with reduced demand. Brent was in a so-called ‘bear market’ territory as it fell by more than 20% since its peak - $86 in early October.

YEARS AGO

10 Years Ago - $110.83 BP and Shell were forced on the defensive by new allegations of pricerigging in the US by four oil traders. The two companies, along with others involved with the oil market, were alleged to have attempted to rig the spot price for Brent crude oil on multiple occasions in the decade prior.

By Eric Doyle

Who owns the Digital Share of Voice in your sector...? It's important to know. If it’s you and your team, then you are the dominant player in the digital version of your markets and you will be taking all the commercial benefits. If it’s your competitors, you have a problem. Perhaps you don't know… Whenever we meet a potential new client we show them where they sit in the digital world. Compare their leadership team, their company digital presence and value against other players in their industry, we show them who owns the digital oxygen in their sector. (But what is the Digital share of voice and why should you care..?) Imagine the sky is full of hot air balloons of different shapes and sizes. These are shares of digital voice in different sectors.

5 Years Ago - $61.50

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The International Tech sector 'balloon' is huge. It's full of big voices like Google, Apple, Microsoft, Meta, Amazon etc. All the huge organisations, all the mid-size, SME and start ups in that sector, all producing digital chatter. Your sector’s ‘share of digital voice balloon’ might be smaller and more niche but there is still a lot of digital chatter. Being the Digitally Dominant player in your sector means you command the right amount and quality of attention, you turn down the voice share of your competition and turn yours up. -You can own the attention, the trust and the conversations in you sectorSo, how do you do this and how do you convert owning the digital share of voice in your sector improvements for your business? You start by understanding what Strategic Social Media is, and how it works. Let’s boil it down and get into the basics of why we use Social Media for business and what it actually does…

Optimise: Having your whole team operating on Social Media in a way that provides algorithmic favourability. Doing the correct things at the correct times, in the correct way in order that the platforms work with you and support you. Drive results: Training the internet to know that you and your team are the answers to the questions that you want to be the answers to. Completing digital circles and driving the internet to your profiles, your content, your websites… total digital ownership. This means looking at Social Media differently. The pandemic has caused hundreds of thousands of people to jump to throwing content at Social Media in the hope that it helps their position, many ended up in a mess. The key is all in the strategy, this is where we reset the organisations commercial circuitry. Digital B2B Influence allows us to build towards becoming the leading technical and commercial digital influencers in our sectors. Some of the results we can expect by owning the ‘Share of Voice’ in your chosen sectors: Qualified Relevance in our markets Target market networks believe you and trust you Strategic revenue, profit and ebitda growth People choose to join your organisation You can own your sector's digital share of voice and receive all the benefits listed above. INFLUENCE - OPTIMISE - DRIVE RESULTS MEASURE - ADJUST - REPEAT

Strategic Social Media allows us to do 3 main things:

As the commercial world moves deeper and deeper into digital, it's important that you and your team have all the information, knowledge and processes to lead in your sector.

Influence: Becoming the leading technical and commercial digital influencers in your sector. Building continual, long-lasting influence and growing meaningful networks who are all looking at and conversing with you and not with your competition,

The key is in the strategy, balancing all of your digital activity with the ambition to own your digital sector twin. The training, the coaching, the repeatable framework and processes and, in the hunger to win.

“GOOD MEDIA MAKES PEOPLE VISIBLE, GREAT MEDIA MAKES THEM THE LEADERS IN THEIR SECTORS...” Eric Doyle is the Managing Director of The OGV Studio, a Digital Media Strategy company whose mission is to Energise your Media for growth. Eric is a Fellow of the Institute of Sales Professionals.

WORLD PROJECTS

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HAIL AND GHASHA SOUR GAS DEVELOPMENT UAE

ADNOC $17 billion ADNOC has taken the final investment decision on the project. The two major EPC packages have been awarded. A consortium of NPCC and Saipem has been awarded EPC Package 1 which involves four drilling centres, one processing plant, offshore structures and 300km of subsea pipelines. Tecnimont has been awarded the EPC contract for the onshore processing plant for the project.

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SABRATHA GAS PROJECT LIBYA Mellitah Oil and Gas Company $8 billion The Antonini Group has secured a $217 million contract to construct the Sabratha platform compression project. This project involves creating a compression unit on a gas platform situated off the Libyan coast and is expected to take 27 months to complete. In addition, the company has also signed an $18.6 million contract for the construction of structures aimed at enhancing drilling processes in the same field.

NORTHERN GAS COMPLEX (NGC) PROJECT ANGOLA

ELK-ANTELOPE GAS FIELD PAPUA NEW GUINEA

New Gas Consortium

TotalEnergies

$2.4 billion

$1.5 billion

Sapura Energy has secured a US$300 million contract for the provision of engineering services, transportation, installation and related activities for the Quiluma and Maboqueiro Platform. The works are expected to be completed by Q4 2026.

The project is entering the bidding phase for the EPC works. The project will be split into three EPC contracts which will cover the upstream development, the four electric LNG trains, and 320 kilometres of onshore and offshore pipelines. Awards for the EPC contracts are expected to be made in Q1 2024, which is also when a final investment decision is expected to be made.

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.

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 5

GENG NORTH GAS AND CONDENSATE DISCOVERY INDONESIA

$2 billion Kaiping 18-1 was discovered in H1 2023 and is estimated to hold proven oil reserves of 146MMbbls. Kaiping 11-4 is estimated to hold 220MMbbls of reserves. Both fields are located about 28 kilometres apart and approximately 100km from existing production facilities. Three development options are currently being considered for the field development.

$5 billion Eni has made a gas discovery through the drilling of Geng North-1 wildcat well on the North Ganal PSC. The discovery is estimated to contain 5Tcf of gas and 400MMboe of condensate. The discovery is located adjacent to the IDD area which includes other stranded discoveries. Due to its location and significant size, the discovery has the potential to contribute to the creation of new production hub in the northern part of Kutei basin.

BALDER X PROJECT NORWAY

CNOOC

Eni

KAIPING OIL FIELD CHINA

ANCHOIS GAS DEVELOPMENT MOROCCO

MARLIM SUL–MARLIM LESTE FIELDS REDEVELOPMENT BRAZIL

$1.8 billion BP has awarded a contract to Allseas to complete the subsea pipelay scope. The contract calls for the installation of approximately 75 kilometres of outstanding length on two 16-inch export pipelines with field termination assemblies (FTAs) in water depths ranging from 1,500 to 2,800 metres, as well as four 10-inch CRA infield lines with FTAs up to two kilometres long in water depths ranging from 1,500 to 2,800 metres.

$2.5 billion Petrobras has completed the conceptual engineering of the Marlim Sul-Marlim Leste project, and basic engineering is currently underway. The fields will be developed by utilising one FPSO, which is expected to feature combined cycle gas turbines. The FPSO is planned to have oil and gas processing capacities of 140,000 barrels per day and 6MMcm/d (212MMcf/d).

OFELIA OIL DISCOVERY NORWAY

GREATER TORTUEAHMEYIM PHASE 1 SENEGAL BP

Petrobras

ROSEBANK OIL AND GAS FIELD UK

Var Energi

Chariot Oil & Gas

Neptune Energy

Equinor

$4.64 billion

$400 million

$250 million

$3.8 billion

Baker Hughes has been awarded a contract to provide a bespoke vertical tree system. The 15-year agreement includes support for existing Balder legacy wells as well as any future developments in the Balder area.

Chariot’s exploration team has identified three promising prospects within the Lixus licence area, all of which have the potential to serve as future development hubs and to be integrated with the planned infrastructure for the Anchois gas project in the same concession. Chariot is now in the final stages of completing the environmental and social impact assessment.

Appraisal drilling has commenced at the Ofelia discovery. The new well aims to appraise and fully evaluate the hydrocarbon discovery in the Ofelia Agat formation. A secondary target is to evaluate an upside of gas charged reservoir in the shallower Kyrre Formation. The well, 35/6-4 S, is being drilled by the Deepsea Yantai, a semi-submersible rig, owned by CIMC and operated by Odfjell Drilling.

Equinor and Ithaca Energy have taken a final investment decision for the field. Contracts that have been awarded include an integrated engineering, procurement, construction, and installation (iEPCI) contract for subsea production systems, umbilicals, risers, and flowlines which TechnipFMC picked up. Odfjell Drilling was awarded a contract for a drilling rig (Deepsea Atlantic) with an estimated value of US$328 million, inclusive of all services, modifications, and options. Altera was awarded a bareboat charter and an operations and maintenance contract for the Petrojarl Knarr FPSO.

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Oil & Gas Decommissioning Could Be A Massive Business Opportunity By Tsvetana Paraskova

Decommissioning of oil and gas platforms in the UK North Sea is a “massive opportunity” for the UK supply chain to keep developing skills and experience to win lucrative contracts overseas, says the UK’s oil and gas regulator.

As oil and gas fields in mature basins such as the North Sea approach the end of their production life, heavy-lift contractors, ports, and the numerous services firms in the supply chain have the opportunity to show world-leading expertise and meet part of the international demand for decommissioning services. Demand for such services is expected to rise not only in the North Sea but also offshore Southeast Asia, Australia, and South America. Australia aims to develop a roadmap to build an Australian decommissioning industry, while companies in Brazil are teaming up with local ports to support the decommissioning of platforms.

UK Decommissioning Sector A “Massive Opportunity” The UK’s offshore oil and gas industry spent £1.6 billion on decommissioning last year, which was its highest annual total spend to date, the North Sea Transition Authority (NSTA) said in its latest Decommissioning Cost and Performance Report in August. The report found that the industry spent a total of around £8 billion from between 2017 and 2022.

www.ogv.energy I November 2023

The cost estimate for decommissioning of remaining oil and gas infrastructure on the UK Continental Shelf is £40 billion. In November 2022, the NSTA and industry agreed a target of cutting the estimate to £33.3 billion by the end of 2028 in an effort to maintain focus on cost-efficient project execution. The target is based on NSTA decommissioning benchmarking and actual cost savings secured by the sector’s top quartile performers in recent years. There is significant opportunity ahead for the sector, with £21 billion of spending on decommissioning expected for the next decade alone. The UK sector has developed a track record of high-standard decommissioning services and activities, keeping costs competitive and making the industry a world leader in decommissioning, the regulator noted. UK suppliers are in line to secure around 70 percent of the work associated with UK North Sea decommissioning projects listed in Supply Chain Action Plans (SCAPs) lodged with the NSTA in 2022. This, according to NSTA, is a clear indication of the sector living up to its North Sea Transition Deal pledge to ensure at least half of spending on decommissioning projects goes to the UK supply chain.

While costs have come down in recent years, the coming decade will be crucial to the UK industry delivering a marked and sustainable improvement in cost efficiency as half of remaining expenditure on UK Continental Shelf (UKCS) decommissioning is expected to be committed in this period. “This represents a huge, immediate opportunity for the UK to further develop its capabilities and reinforce its status as the global centre of decommissioning excellence,” NSTA said in the report. “Building the capacity and capability of the UK’s supply chain will not only deliver UK decommissioning but will position the industry to win lucrative contracts for decommissioning work overseas. Its experience and expertise could also be transferred to other energy sectors which will require decommissioning services, such as offshore wind.” Operators and suppliers need closer collaboration, with clear decommissioning schedules and plans, to provide a balanced view of performance and drive improvements over the next decade, according to the regulator.

DECOMMISSIONING “The North Sea decommissioning sector is highly active and productive, and the industry is ideally placed to realise the massive £21 billion opportunity which will come its way over the next 10 years,” said Pauline Innes, NSTA Director of Supply Chain and Decommissioning. “However, operators must redouble their commitment to collaborate with the supply chain and plan even more effectively if they are to overcome challenging market conditions and remain competitive on cost,” Innes added. Bob Fennell, DaRT co-chair and North Sea executive vice president at Harbour Energy, said, commenting on the NSTA report: “Collaborating and sharing data is an important first step to providing the supply chain with the visibility and confidence they require to meet UK demand for such works in a timely and cost-competitive way.” Sam Long, Decom Mission Chief Executive, said: “Decommissioning is but one of many market opportunities that members face, with the continuing advancement of the energy transition and the international need for decommissioning services.” “Transparency of coming works and interaction between the owner/operator community and the supply chain is key to ensuring that the services, preferably offered from within the UK, exist to meet this current and future demand,” Long added.

Decommissioning Survey During SPE Offshore Europe in September, Decom Mission launched a survey of the global decommissioning supply network – which will be the first to provide primary insight into its current capability and capacity, as well as providing a snapshot of sentiment across the sector. Decom Mission plans to publish a report on the survey in May 2024, which is expected to reflect the current state of the decommissioning supply network across the oil and gas, nuclear energy, and renewable sectors. To carry out the survey and draft the report, Decom Mission has partnered with data science experts – and Decom Mission member – Empirisys, to develop and deliver the survey, following the impact made by the latter’s recent work in delivering the largest survey of its kind for Step Change in Safety. “Currently, there is constant emphasis on future opportunities within the energy industry; Decom Mission is adamant that those of the present should not be forgotten about,” Decom Mission’s CEO Long commented. “Decommissioning plays a crucial role in the energy transition and this survey focuses on the opportunities of today and tomorrow – that’s vital to the survival of this industry.”

Decommissioning Deals At the end of September, Offshore Energies UK announced its shortlist for the Decommissioning Conference awards in November. The Excellence in Decommissioning Awards recognise companies that have performed to an exceptional level within the offshore decommissioning industry. The award criteria can cover any aspect including project execution, design, innovation, HSE, cost performance, and contribution to the energy transition. Repsol Sinopec Resources UK Ltd, Spirit Energy, and TAQA UK were shortlisted as the Operator Category Finalists, while DOF, Stork, and Utility ROV Services Limited were picked as Supply Chain Category Finalists. “Decommissioning is an integral part of the lifespan of any offshore project and the awards are a great opportunity to celebrate the key role our companies and their people are playing in this innovative space,” OEUK’s HSE and Operations Director Mark Wilson, said, commenting on the shortlists. Meanwhile, ocean services provider DeepOcean said in early October it had successfully completed a significant decommissioning project on Fairfield Energy’s Dunlin Alpha platform on the UKCS. As part of its scope, subsea specialist DeepOcean removed 6 subsea conductors and 4 vertical supports at varying water depths and removed the upper conductor guideframes with an estimated weight of 400 tonnes, together with

the design and installation of bespoke clamps. Key subcontractors who assisted in delivering the scope of work include Claxton, Machtech, and Global Energy Group. The Dunlin Alpha installation, located approximately 137 km northeast of Shetland in a water depth of 151 m, produced its first oil in 1978. Fairfield Energy acquired the assets in 2008 and took over full operatorship in 2014, maximizing production during its latelife stage and then progressing its subsequent decommissioning programs. Port of Blyth welcomed in August their largest oil and gas decommissioning project to date into their Battleship Wharf terminal, the home of the Port’s unique decommissioning facility, operated in partnership with Thompsons of Prudhoe. Ideally located midway between Aberdeen and Great Yarmouth, Port of Blyth is a leading UK offshore energy support base and is well-placed to support major decommissioning projects in the North Sea and beyond, the port says. Another port, Porto do Açu in Brazil, signed an agreement with Brazilian state energy giant Petrobras to provide support to the decommissioning of oil and gas platforms. The agreement makes docks available for platforms undergoing decommissioning to be temporarily docked at until the final destination of the unit has been decided, in accordance with best international practice on green recycling and sustainability (ASG), Petrobras said in September. The agreement is part of Petrobras’s plan to decommission a total of 26 platforms by 2030. In Australia, the government is looking to establish an Australian decommissioning industry for offshore oil and gas. The Australian Department of Industry, Science and Resources invited in September stakeholders to submit views and feedback on how Australia can establish an industry to decommission offshore oil and gas infrastructure. About US$38 billion (AUS$60 billion) worth of offshore decommissioning activity is expected to occur in Australia over the next 30 to 50 years, the government says. 

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EXCEED: chosen by industry, leading decommissioning Risk and uncertainty are inherent in decommissioning. Faced with faster well decom cycle times and the variety of challenges inherent in re-entering old wells, each operator must accelerate the learning curve to minimise time and cost, whilst ensuring all activity falls within regulator guidelines. Having honed our well abandonment capability over the past nine years supporting the abandonment of 150+ wells and 12 vessel-based well abandonments, EXCEED owns the most diverse decommissioning track record within the North Sea. That experience includes well decommissioning using platform rigs, hydraulic work over units, jack ups, semi-submersibles, LWIV and CSVs. We have created a market-leading decommissioning capability that is trusted by the industry’s biggest names to execute some of the North Sea’s most significant and challenging decommissioning campaigns. This reputation is reinforced by our status as Well Operator. We approach each project with an open and constructive mindset, collaborating across the industry to ensure efficient delivery of results. Bringing Experience to the Table The significant, and frequently unforeseen, challenges associated with this learning curve are consistently mitigated by the well management and decommissioning expertise of EXCEED. Those challenges include aging infrastructure, wellheads and trees, and a lack of well access equipment. These types of challenges are combined with the fact that our industry has lost to retirement many of those with the relevant technical “know how” of technologies that span four decades. EXCEED mitigates that, by applying our deep historical and current knowledge & understanding of the regulations and requirements for each well abandonment campaign. In doing so, we provide highly specialist solutions, from planning, including reverse engineering, through to well abandonment and subsea pipeline removal. We make use of the vast in-house knowledge library to assess the optimum method of compliant abandonment, whilst ensuring the industry’s most relevant personnel and equipment are assigned to the campaign. This track record translates into cutting-edge decommissioning strategies which, whilst bespoke, have significant replication value on multi-well campaigns, which can be mobilised and transferred across projects to ensure safe start ups and efficient operations for those operators who require specialist assistance.

www.ogv.energy I November 2023

Collaborative Relationships: the X Factor The decommissioning sector remains challenging, and it is EXCEED’s industry status, influence and track record which sets us apart and allows us to deliver industry leading results. Our ethos is to lead the energy transformation, and we work hard to ensure our partners share our mindset to improve through technological innovation, shared risk and unique, outcomeled commercial models. EXCEED has the knowledge and confidence to challenge industry standards, applying an engineered and pragmatic approach. Our purpose is to disrupt the norm, working as genuine partners to our clients and collaborating with the supply chain, to develop the tools and methods which will gain the greatest efficiencies. The trust our operator clients have in our ability to challenge whilst remaining complaint also plays a critical role, as they consider early adoption of our innovative approaches to decommissioning. These can range from the bespoke design of equipment, to identifying novel ways in which to reuse existing equipment to abandon wells in the safest, most efficient manner. EXCEED has exposure to multiple decom projects and provides the operator with the continuity of a dedicated team of decommissioning experts that are 100% focused on decom projects, versus the client cost of building internal capability for intermittent campaigns. In the past 24 months, the volume of decommissioning work awarded to EXCEED has necessitated the exponential growth of the decom team, which now comprises over 40 subsea well experts and decommissioning engineers, led by Head of Decommissioning, Bart Van de Laar and located in dedicated premises within Aberdeen city centre. As independent solutions provider, we are impartial in the technology we select, and ensure the optimum solutions are deployed in conjunction with the breadth of capability and depth of experience of our team. That approach has been applied to a wide range of projects during 2023 including: Providing a team to support one of the North Sea’s seminal conductor recovery programmes, utilising our partner WellGear’s unique unit throughout the first three quarters of 2023.

Full Well Management Services for the planning and execution of well P&A to enable the option for field repurposing. Thru tubing abandonment, using a light well intervention vessel in central North Sea. Supporting in the design, manufacture, testing and installation of tree and wellhead strengthening structures, and well control access for subsea P&A operations currently underway. This month (November 2023), EXCEED will commence its second vessel-based decommissioning campaign, whilst early 2024 activity will include a semisubmersible project, and a 10 well jack up campaign, working as Well Operator in the SNS. Transforming People, Transforming Decommissioning The North Sea continues to provide the blueprint for the vast majority of future decommissioning activity. Complementing our unique well engineering capabilities, EXCEED is responsible for assisting our clients in developing and implementing the performance disciplines which are informing this global energy sector, resulting in accelerated learning and maximising replication value as quickly as possible. With a track record in delivering proven Performance Improvement solutions across all stages of the well lifecycle, EXCEED’s specialist offshore and onshore coaches have excelled in aiding decommissioning project teams which have delivered worldclass performance safely, compliantly and significantly under budget. Our clients consistently experience results in these key elements, of particular relevance to any decommissioning campaign: Enhanced safety Improved well abandonment times Reduced costs An engaged and motivated rig team “I was very impressed with the professionalism and commitment shown by Exceed to this role. We maintained very high standards throughout this campaign and that allowed us to achieve world-class results.” Abandonment Superintendent

For more information visit www.xcd.com

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EXCEED’s well decommissioning experts have worked on some of the industry’s largest decommissioning campaigns, resulting in unrivalled knowledge, best practice and the use of innovative tooling methods.

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Navigating the Complexities of Decommissioning

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The EU states that “Decommissioning offshore oil and gas infrastructure is the process of permanent resealing of wells such that remaining hydrocarbons cannot leak to the sea, or move between different rock strata, and the removal of offshore oil and gas infrastructure from the marine environment with the objective of leaving a clean sea”.

In practice, decommissioning a well involves three main steps. The first is dismantling the producing and transportation facilities. The second is the plugging and abandoning of a well and the final step is restoring the producing area to its original state. Decommissioning occurs because of a commitment from the operator when permission is granted by the government to develop an oilfield. Once the oilfield has passed its economic life (when production has declined) the operator must leave the well site as they found it. A challenge for operators when performing decommissioning activities is that often the wells to be decommissioned can have numerous issues, such as well integrity, formation challenges, or mechanical obstructions, and as such it is important to select the ‘right’ partner to perform decommissioning activities. One such partner able to support steps 2 and 3 of the well decommissioning cycle is Stena Drilling. Stena Drilling is one of the world’s foremost independent drilling contractors managing a global business, consisting of five ultra-deepwater drillships and two semisubmersible rigs. The organisation is regularly quoted as being a contractor of choice due to its excellent operational and safety performance along with the ability to offer the client a full suite of services when considering offshore projects. Stena Drilling has the skillset to support clients from the exploration and appraisal phase of a project through to the safe decommissioning of wells at the end of the well cycle. When it comes to decommissioning, Stena Drilling has developed into an industry leader. Stena Drilling vessels have performed 79 Plug and Abandonment (P&A) wells with many of these operations being performed in UK and Irish waters in recent years using the Stena Don and Stena Spey.

Impressively the team on the Stena Don have decommissioned 41 wells at the time of writing for various operators in the UKCS and NCS. This number is forecast to increase in 2023/ 2024 as the Stena Don is currently operational and performing P&A activities in the UKCS. This campaign has seen the crew tackle various challenges including fast-paced operations which have seen wells completed ahead of client AFE timings, dealing with the unknowns of abandonment operations where additional precautions are required to be taken to maintain high standards of process safety. Additionally, working through contingency operations to ensure well barriers are put in place and tested in accordance with industry standards. A further advantage of Stena Don is that it is not a dedicated P&A unit, but instead also functions as a highly capable drilling rig offering clients the full range of drilling services. This means that the Stena Don can switch between performing P&A operations to development drilling activities with relative ease. As an example of this functionality, Stena Don is currently scheduled to swap from batch P&A mode to development drilling mode for its current client in early 2024. This allows for clients to plan production adding activities in amongst P&A commitments to the regulator. In addition to the Stena Don and Stena Spey’s impressive decommissioning track record, Stena Drilling also have recent experience of batch P&A operations using our DrillMAX class 6th Generation drillship fleet. In 2021 the Stena Forth completed the decommissioning of 4 wells in Israel. These wells were complex as an intervention riser system was required to allow access to the subsea Xmas tree and the water depth was considered to be shallow for a DP3 Drillship at just over 200m. The wells also required extensive coiled tubing operations which necessitated the

installation of a coiled tubing spread and a coiled tubing lift frame. Other operations involved pulling completion and setting cement plugs at various intervals. Decommissioning operations offer a unique set of challenges which crews must adapt to and overcome. One of the biggest challenges to decommissioning is the unknown as many of the wells that need to be decommissioned are over 40 years old. Additionally, decommissioning is typically a faster-paced environment compared to other types of wells, due to the short period for each well and the various contingencies that must be ready at short notice. Being prepared for the next well in the sequence and identifying the right contingency equipment is crucial for an efficient batch P&A operation. At Stena Drilling the project team, working closely with the client, plan for upcoming operations to maximise uptime for the unit. This includes interfacing with 3rd Party suppliers to ensure the smooth installation of equipment required for decommissioning activities onboard the rig by working closely with clients Stena Drilling can provide safe, predictable, and cost-effective solutions for P&A activities based on the organisations’ extensive experience to date. As mature fields head towards cessation of production, the number of wells to be decommissioned are forecast to increase year-on-year. For operators to minimise their decommissioning liability, it is crucial that they partner with contractors that have the expertise and equipment to safely and efficiently complete decommissioning projects. Stena Drilling are an excellent example of a contractor who can provide the required support for an operator when embarking on a decommissioning project. 

Driving safe, cost-effective operations in Well Construction and Well Decommissioning. Stena Drilling is the strategic partner of choice. www.stena-drilling.com

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The Role of Robotic Tank Cleaning in Decontamination and Demolition

Maintaining Standards Operators of high hazard installations are also closely monitored by environmental regulators. During outages of tanks, the highest standards are demanded of such companies. Strenuous measures are taken and enforced to ensure that during routine tank cleaning, the possibility of ground contamination is minimised. These standards and duty of care for the environment persist during any decontamination process ahead of demolition. Operating companies are thus looking for the highest standards in both environment management and safety during normal operations, but also as their plants are deconstructed at end of life. At the same time, demolition contractors are looking to use mechanical equipment because of the efficiency it delivers.

Decommissioning of oil storage tanks requires decontamination of the asset, before demolition can begin. In most cases, this involves the bulk removal of sludge and residual oil deposits in the safest and most environmentally-friendly manner. The demolition industry has long recognised the benefits of using mechanical plant and equipment to tear down and remove steelwork. Modern demolition techniques have made great strides in terms of ensuring safe processes and they excel where clean assets are concerned. However, a desire for greater assurance regarding the environmental control and fate of oil residues places additional demands on the techniques that have traditionally been employed. Dependant on the contracting approach taken by an operating company in their dealings with the demolition company, the process of ensuring that the assets are in fact clean, can fall to those whose experience lies primarily in the demolition field rather than the decontamination field. It is the natural reaction of a demolition company to expect to use mechanical plant for such a purpose, but they may not be aware of the latest techniques and equipment available. Equally, they may have little experience or understanding of the demands placed on modern operating companies by environmental regulators or main boards increasingly conscious of their company’s valuable reputation as a sustainable enterprise, aware of its Environmental, Social and Governance (ESG) responsibilities.

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Reputation Management In today’s connected world, reputation is everything. For both demolition contractor and operating company, news of accidents, or environmental incidents spreads fast, leading to negative public perceptions. Adverse incidents can irreparably damage a company’s reputation, undermine investor confidence, and directly impact share prices. Routine cleaning of tanks which are to remain in service, can be achieved through a range of different techniques. The traditional approach of sending operatives in with shovels, assisted perhaps by bulldozers, to manually remove sludge and residues from tanks is inherently hazardous. It demands a lot of both their personal protective equipment (PPE) and their operating methods such as permit to work (PTW) systems, to ensure their safety. Failures of either PPE compliance or PTW System compliance are likely to put operatives at risk. When this risk manifests itself during a confined space entry (CSE)*, consequences can be high. It is for this reason that operating companies, especially those who work with demanding operating management systems are required to do all that they can to avoid manned CSE when other alternatives are available. For safety reasons, the market is starting to value ways to conduct tank cleaning using mechanical methods that isolate the person from the confined space risk.

At this interface between demolition contractors’ expectations and running plant cleaning techniques, mechanical approaches such as robotic tank cleaning are becoming more popular. The initial investment in implementing automated systems is offset by considerable risk reduction, minimised expenses associated with accidents, injuries, and litigation, reduced labour costs and even lower insurance premiums. Flexible and Quick Response Robotic techniques are flexible, accommodating a wide range of tank designs and contents, with an ability to operate in Zone 0, Class 1 Div 1 Ex-rated atmospheres. They utilise the addition of hot water or diesel cutting agents to ensure that previously stubborn sludges and deposits are released by the tank to the suction systems of the robot. There are a number of tips and tricks to effective robot operation, requiring an investment in training and development by the contracting company. Set up on site is rapid, robots are of course not susceptible to fatigue or elevated tank internal temperatures and in many circumstances tanks are cleaned quicker than other approaches. In conclusion, by prioritising use of robotic tank cleaning, demolition contractors and operating companies can protect their brand image, enhance stakeholder trust, and maintain a positive market valuation. Employing manless entry systems, such as Re-Gen Robotics’ tank cleaning service can significantly reduce or eliminate many of the headaches and costs associated with oil storage tank cleaning. * (‘permit-required confined space entry’ as per OSHA)

For more information visit www.regenrobotics.com

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Navigating the Digital Knowledge Era: AI's Impact on Preserving and Sharing Institutional Expertise The Energy industry is on the cusp of a significant challenge: the widening knowledge and skills gap created by the impending retirement of experienced workers. As these seasoned employees prepare to exit the industry, they take with them invaluable institutional knowledge. This growing void poses a critical concern for organizations, which must find innovative solutions to address the challenge. Forward-thinking Energy companies are turning to advanced technologies to bridge this knowledge gap.

The Role of Cutting-Edge Technology Cutting-edge technology solutions are emerging as essential tools in the effort to bridge the knowledge gap. These solutions leverage advancements in AI-powered knowledge delivery and centralized knowledge preservation to offer a multifaceted approach to addressing the challenge:

1. Capturing Institutional Knowledge: Advanced technology provides retiring workers with intuitive platforms to easily document their expertise as part of everyday activities. Whether it's field insights, safety protocols, or operational best practices. 2. Empowering Frontline Workers: Accumulated knowledge is securely housed within centralized repositories alongside operational, technical, and product-related data. AI-driven search and chat capabilities enable frontline workers to readily access precise information and expertise as needed. 3. Informed Decision-Making: The historical data, best practices, and insights support informed decision-making. This can lead to enhanced operational efficiency, reduced downtime, and improved safety protocols. 4. Training and Onboarding: Shared knowledge provides mentorship to new and younger employees, ensuring a smoother transition and shorter learning curve

Realizing Tangible Benefits

Enhanced Safety: Access to historical safety data and protocols ensures that safety remains paramount, mitigating the risk of accidents. Operational Excellence: With the average worker spending 5 hours per week waiting for information and up to 8 hours per week working inefficiently, implementing knowledge capture and delivery solutions can dramatically impact the company’s bottom line. Innovation: The innovative potential of these technologies can identify opportunities for process improvement and innovation. Advanced technology solutions such as Onsight NOW by Librestream Technologies are emerging as powerful allies for Energy companies facing the imminent knowledge and skills gap due to retiring workers. They offer practical and efficient means to capture, retain, and disseminate institutional knowledge, ensuring the industry continues to thrive and meet future energy demands.  For more information, visit www.onsightnow.com.

By leveraging these advanced technologies, Energy companies can reap substantial rewards:

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Effective decommissioning campaigns hinge on the pivotal role of lump sum cost modelling With approaching deadlines for net zero targets, energy companies are transitioning into new areas in order to continue supply of commodities to the market. In this light, decommissioning is becoming increasingly important. However, to overcome the execution barriers, lowering the cost for wells that need to be plugged and abandoned calls the shots for the investment decision. Despite our industry’s innovation in new technologies and experience gathered over many years, the budgeting workflows and communication within a project team seem to have stagnated. Reflecting the daily conversations we have with drillers, we see there is a wide gap in how teams approach their uncertainty assessment and tracking of cost and time. Is it possible for lump sum cost modelling in decommissioning to yield mutual benefits for operators and contractors? Lump sum drilling model has risen as one of the initiatives for improving cost efficiencies. This commercial model has proven very successful and equally unsuccessful for contractors whose time and cost planning didn’t quite work. The challenges of lump sum engagement involve poor budget planning due to lack of well data and incomplete overview of all potential risks. As time is critical with thousands of wells queued to be P&A’d, the most reasonable approach seems to be to abandon wells in batches with multi-well campaigns outsourced to decommissioning specialist houses. What benefits does lump sum bring to decommissioning? The benefits of the lump sum commercial model include cost guarantee and transparency for the Operator. The Operator frees resources to engage with exploration and production of new, higher value resources and reserves.

www.ogv.energy I November 2023

The contractor, on the other hand, improves accuracy in drawing a more realistic cost model of the end result of the decommissioning campaign, taking into account potential risks and unexpected events. Learning from previous experiences and having a complete overview of operational trends, time and cost allows the Contractor to improve its skills to execute projects within a set commercial framework. Incorporating probabilistic lump sum cost modelling offers a secure approach Probabilistic cost modeling methodology considers all possible project outcomes and risks that can arise during decommissioning campaigns. Using a Monte Carlo simulation approach helps the engineering teams to identify why a well may be more or less expensive than planned. Hence, well cost planning is done more accurately and there is greater possibility of the project being sanctioned and reduced potential for budget overruns. Some of the globe’s largest energy and energy services companies enjoy significant improvements in their uncertainty assessment with cost planning through implementation of AGR Software’s iQx™ probabilistic planning tool. Their teams achieve greater transparency of operational data, improved information input for investment decisions and enhanced understanding of correlation between costs and risks. iQx™ outputs provide a realistic range of well time and cost ranging from the minimum (P1), through the most likely (P_Mean) to the maximum (P99). In this context, iQx iQx™ means that only 1 % of the realizations came out lower than this value and P99 means only 1 % came out higher. With one decommissioning project and budget set on the Mean Percentile (the most likely), the outcome of the operation’s cost would most probably be faster and cheaper

in most cases (approximately 60-70 %) of the time assuming the risk exposure is low. In other words, approx 30% of the time, the decommissioning project would exceed the sanctioned budget. With data library of previous wells, the teams can set up cost models which improve as the operations develop and as a result, the average cost model success rate improves. The overall cost level of a batch of wells decommissioned fits within the sanctioned budget. Key benefits of cost planning with iQx™: Modern software architecture with OpenAPI, SSO and option for local deployment Comprehensive campaign time and cost modelling with learning curve Greater transparency of budgets and risk exposures Enhanced exploitation reference data

historic

Improved cost modelling standardisation with data tagging and templates Selective data output with autodistribution Seamless data flow with external sources for empowered drilling time and cost analysis Improved collaboration across all project partners ABOUT AGR SOFTWARE AGR Software’s iQx™ platform helps energy companies to digitise their well delivery process with immediate results. By believing that collaboration empowers knowledge sharing and creates improved decisions, the company is focussing on developing a plugand-play data library that makes life easier for drilling engineers.x

For more information visit www.agr-software.com

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Extending the Life of Subsea Fields and Structures: The Potential of Flexible Riser Reutilisation The Impulse Group, Specialists in Flexible Pipe Integrity Management The oil and gas industry is constantly seeking ways to maximise the life of subsea fields and structures to ensure efficient operations and reduce costs. A key focus within this industry is the extension of the design life of flexible risers. These vital components of subsea infrastructure play a crucial role in offshore exploration and production. However, the possibilities for extending the design life of flexible risers go beyond their original applications, offering opportunities for increased reutilisation in various oil and gas exploration areas. Flexible risers have historically been utilised for their intended purpose and often retired once their design life is exhausted. Yet, industry experts recognise the potential for these assets to be reutilised, not only to extend the life of aging flexible risers but also to optimise exploration in new areas. To harness this potential effectively, a comprehensive and integrated approach is required, with consideration given to various factors that influence reutilisation. To facilitate the reutilisation of flexible risers, design considerations are paramount. One key aspect is the incorporation of intermediate connections during the initial design phase. This foresight allows for safer and more convenient reuse, especially in applications where the original riser may not perfectly align with the new requirements. Moreover, field developments can contemplate using used flexible risers as a cost-effective alternative for early production systems. This approach not only reduces capital expenditure but also minimises lead times associated with manufacturing new risers. Additionally, integrating retired flexibles into a spares philosophy can further support the life extension of aging flexible assets, ensuring a more cost-efficient and sustainable approach to subsea operations. The feasibility of reutilising flexible risers is contingent upon several factors, including the condition and operational history of the asset. A thorough examination of the riser's past applications, maintenance records, and any previous modifications is essential. This information provides critical insights into the riser's integrity, structural soundness, and whether it can be adapted to meet new requirements.

Quality control is of utmost importance when considering the reutilisation of flexible risers. Rigorous testing and inspection processes should be implemented to ensure that the riser meets the necessary standards and safety requirements for its intended purpose. Any potential weaknesses or degradation must be identified and addressed before reutilisation can proceed, mitigating the risk of operational failures. It is important to note that the practicalities and advantages of reutilisation can vary significantly depending on the operator and the specific exploration area. Some regions may have stricter regulatory requirements, while operators may have varying degrees of willingness to explore reutilisation opportunities. This underscores the importance of a flexible and adaptable approach that considers the unique circumstances of each project. By embracing the reutilisation of flexible risers, the oil and gas industry can achieve significant cost and time savings. The reutilisation of existing assets eliminates the need for new riser manufacturing and reduces lead times associated with procurement, fabrication, and installation. This not only contributes to cost efficiency but also enhances the overall sustainability of offshore operations. The extension of the design life of flexible risers is a primary focus in the oil and gas industry, but the potential for their reutilisation offers an innovative and sustainable approach to subsea field development.

By integrating design considerations, assessing operational history, and maintaining rigorous quality control, operators can unlock the possibilities of flexible riser reutilisation. This not only optimises operational efficiency but also contributes to cost savings, reinforcing the industry's commitment to achieving sustainable and economically viable subsea operations. The Impulse Group offers a range of services for the oil, gas and energy industries, including asset integrity management, decommissioning, project delivery, 3rd party inspection and testing of flexible products. Our team of highly specialised and experienced engineers and technicians can help minimise risks and extend the lifespan of your operations, increasing efficiency and maximising output. We provide support during the pre-FEED, design and manufacturing phases to ensure projects are completed on time and within budget. We offer inhouse or remote training on flexible product technology, as well as a variety of specialised components, such as repair systems, clamps, bend restrictors, and centralisers, to support your projects. The Impulse Group employs over twenty people with a combined over 140 years of experience with flexible pipe products. We have bases in Morpeth and Aberdeen supporting clients in Norway, Canada, Denmark, Malaysia, Nigeria, Ghana, Vietnam and India.

Specialists in Flexible Pipe and Subsea Integrity Management

support@theimpulsegroup.com

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For further information about our capabilities, please visit our website at www.theimpulsegroup.com, email info@theimpulsegroup.com or scan the QR code.

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Highlight On: NEMESIS EQUIPMENT

The first in a new series of interviews from Intervention Rentals will focus on Nathan Reid, Business Development Manager, and the Nemesis Equipment division.

What is unique about the Nemesis equipment? It’s the sheer versatility and reliability. Whether it’s working in pits, at height or on environmentally sensitive clean ups, we have a unit, solution and commercial package to furnish our clients requirements. The feedback we receive from our clients is that our aftersales service is second to none in this field. Because we have units all over the world, the UAE, Malaysia, Thailand, Australia, India, should the client have a unit go down or they damage it in some way, we immediately support with parts, replacements, or servicing and we are on hand to pick up a phone 24/7. Our clients really appreciate the service and support we offer, not just within NEMESIS but companywide.

Who is your typical client?

Nathan, can you tell us a little about yourself and what you do for Intervention Rentals?

Absolutely any type of industrial operations that require hydrocarbon removal, clean up or transfer as well as cleaning and blasting. We have serviced and continue to support, drilling companies, drill ships, all types of marine vessels and docks, fixed platforms & structures as well as workshops, yards, and general facilities. 

I have been in the Drilling Waste Management (DWM) Industry for about 28 years, and have worked in Ops, Projects and BD. These roles took me and my family around the globe, from UK, and across diverse locations in Europe, the Middle East, Asia and South America. I have loved experiencing new cultures and dealing with many types of needs and issues. For Intervention Rentals, I look after the commercial aspects of our Nemesis brand of pressure equipment of which, we are looking to expand our portfolio of offerings further.

Can you tell us about the Nemesis Suite of pressure equipment? Under Nemesis we offer proven, reliable, best in class equipment rentals ranging from our MKIV Mud Vacs, our 30:1 Hydra Clean Units to our EcoQuip2 Hydro Blasters. All these solutions are designed for quick, easy and efficient methods of cleaning the toughest of environments. That’s fairly standard, not only for the industry but our standard service provision. They are all portable, small but mighty, meaning the client can utilise them fully for those hard-to-reach areas. We are also looking to diversify outside of Oil & Gas and into Sustainability and Renewable markets. In the coming months we will see more in the ‘Highlights On’ series from Intervention Rentals and you can see the range of premium pressure equipment that Intervention Rentals has by visiting www.interventionrentals.com or by reaching Nathan at nathanreid@interventionrentals.com

For more information visit www.interventionrentals.com

INNOVATION & TECHNOLOGY SPONSORED BY

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Innovative Decommissioning Efforts in the UK: The Rise of Hybrid Battery-Powered Vessels By Benson John MSc CEng MIMeche Assistant Manager - R&D Tax Incentives

The UK's decommissioning landscape is undergoing a ‘green’ more sustainable and environmentally responsible decommissioning transformation driven by groundbreaking initiatives. An endeavour that futures. The implementation of hybrid battery-powered vessels not only has been transforming the way the decommissioning sector operates aligns with these environmental objectives but also delivers economic is the advent of the hybrid battery-powered vessel. These vessels benefits. Reduced fuel consumption, lower emissions, and improved exemplify cutting-edge approaches adopted by the UK to efficiently efficiency contribute to cost savings in decommissioning operations. and sustainably address decommissioning challenges. Hybrid These vessels serve as a testament to the nation’s determination battery-powered vessels provide a compelling strategy to to create a greener future. As the UK improve decommissioning processes. These vessels As the UK continues to pioneer approaches to combine traditional energy sources with cuttingcontinues to pioneer decommissioning, hybrid battery-powered vessels edge battery technology, reducing pollutants, fuel approaches to represent just one facet of the broader transformation. consumption, and operating expenses. This grounddecommissioning, hybrid The country's decommissioning sector is on a breaking method is especially useful for offshore trajectory towards cleaner, more efficient, and more decommissioning projects as they frequently include battery-powered vessels sustainable practices and is a testament to the isolated and ecologically delicate regions. The represent just one facet innovative spirit that characterises the UK's approach collaboration among prominent offshore services of the broader to the challenges of the modern energy landscape. providers and their use of a hybrid battery-powered transformation. vessel exemplifies the ongoing transformation in the For companies involved in innovative projects, tackling decommissioning sector. Their commitment to reducing unforeseen and challenging developmental work to drive the environmental footprint and improving operational technological innovation warrants the exploration of HMRC’s R&D Tax efficiency reflects the broader trend towards sustainable practices Relief Scheme. As a leader in innovation funding, Leyton offers expert within the industry. guidance and support for firms seeking financial backing for their R&D endeavors. Leyton's extensive experience can assist companies in The UK's approach to decommissioning is now intrinsically linked to availing significant tax relief for their pioneering work. By partnering sustainability. The deployment of innovative ‘green’ vessels underscores with Leyton, companies can confidently apply for R&D funding, ensuring the commitment to cleaner and more efficient decommissioning processes. By integrating green technologies, the UK is moving towards their innovative efforts are maximally rewarded. 

www.ogv.energy I November 2023

For more information visit: leyton.com

OUR DIGITAL INDUSTRY SPONSORED BY Our CTO for Data, Mike Stewart has been

Mike Stewart CTO for Data

Stewart involved with Energy data and Information Management for more than 17 years and how helps customers leverage Sword’s full data capability across sectors

www.sword-group.com

and disciplines.

A RENEWED FOCUS The Northeast commute to Aberdeen from any direction is dominated by on and offshore wind turbines. The horizon is a literal sign of the times as investment shifts away from traditional energies towards renewables. The rig count and boat traffic may be increasing in the local ports and harbours, but the majority are in service of the rapid expansion of the offshore wind infrastructure, with turbine blades rather than drill pipe adorning the heavy haulage on our roads. As the renewable industry grows rapidly, how will Scotland meet the demand for digital platform and data skills in green energy, particularly when traditional oil & gas markets are drawing on the same talent pool? Sword’s footprint in the renewable sector continues to expand in 2023, likely doubling in 2024. With this growth we will support new market entrants, green energy pioneers and large energy organisations to build scalable digital platforms and derive more value from their data assets. Among this growth, we have seen a spike in demand for expertise in platform and network security as company’s invest in becoming more cyber resilient, reducing their vulnerability to external threats. Additionally, our data teams have brought in graduate and junior career talent to meet the needs for data engineering, data science and analytics to drive better decision making.

What’s driving the skill demand? Our renewables customers often face geographic challenges with their assets and infrastructure more widely dispersed than typical oil and gas operators, normally in challenging areas on the far North and West of the UK. Wind, solar and geothermal are onsite intensive operations, and despite technological advancements in monitoring and maintenance, require a skilled workforce ready to work in challenging environments.

need to come from training and development, technology advances, efficiency gains and collaboration within the supply chains. The growing emphasis on real-time operations in the renewable sector poses a big talent challenge. Traditional energy companies are investing heavily in real-time operations and maintenance, there isn’t the same legacy of talent and skills as in other disciplines. Developing tailored talent takes time, so in the meantime it’s up to us, in the service supply chain to come up with the shortfall. These capabilities have been successfully outsourced or offshore, but that relies on consistent process and quality management, not to mention the challenge of increasing costs and attrition rates in lower-cost centre geographies. On top of these challenges, Cyber resilience continues to concern organisations throughout the energy industry, it’s no longer if an attack will come, but when and how a company have measures in place to protect its critical infrastructure and data. Renewable and utility companies have the additional pressure of maintaining realtime electrical supply to the grid and protecting customer’s private and financial data. There’s been a correlated increase in investment in OT and Cyber skills – both training and awareness, strategic consultancy to devise policy and governance, and operational support roles to fasttrack security operations programmes to minimise vulnerability. As the renewable sector scales and matures, it must determine whether to buy or build the system and app capability it needs to fully realise the value of its data. We are seeing growth spike in demand for Scaled Agile, DevOps, Product Development, and technologies like FME and PowerPlatform as customers increasingly leverage cloud-based technology, GIS, and low-code app building to reduce waste within workflows and provide self-service data portals.

What role does Sword play? Sword has a dual role in the Energy Transition; to support its traditional energy customers diversify beyond Oil & Gas, and to help develop relevant platform and data talent. The good news is that lots of the capability, experience and skills that exist in traditional energy disciplines are transferable. The demand for modern digital skills, PowerPlatform for example, is the same no matter which sector we’re servicing. The need to innovate, to code, and do more with less and to automate manual process, is as relevant in renewables as anywhere else. The requirement for trusted data, to drive decision making, is top of most digital maturity league tables.

Talent with previous Capital Project experience is a common ask in renewables, and the North Sea oil and gas legacy has a huge amount to offer here. With this we have seen an increase Capability, in requirements for data and information management Sword continues to develop a talent pool with relevant experience and expertise to help control, manage and maintain skills to meet the demands of renewables and the information workflows, as companies rapidly design skills that exist in wider energy market. In some areas, we need to re-skill and bring online new infrastructure. Software, practices, and train our workforce, but retain the energy domain tradtitional energy and roles proven to add-vale in oil and gas are replicated knowledge that sets us apart. in the renewable sector and are drawing on a limited disciplines are We have acquired in key disciplines and will continue talent pool. We, as an organisation, are playing our part transferable to do so, collaborating with key strategic partners to through supporting graduate talent from local UK and bring capability to customers in expanding regions like the Scottish universities, but a shift of capability and capacity from traditional energy markets will take time. The shortfall will Middle East. 

About Sword: As the North Sea’s largest provider of Data and Digital services, Sword focuses on solving the industry’s most critical business 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

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

RENEWABLES

CORPORATE PARTNER

www.renewableuk.com

RenewableUK members are enabling a just transtion to a net zero future. Focusing on continuous improvement around the three pillars of our Just Transition Tracker - People, Place and Planet These inspiring companies are a true showcase of the best that our industry has to offer.

GETTING THE NORTH SEA ELECTRIFICATION WHEELS MOVING By Mark Dixon, Co-Founder and Director, Cerulean Winds With political and public scrutiny of the North Sea at an all-time high, it is more important than ever that the sector makes progress on slashing harmful emissions arising from the production of oil and gas. By 2025 the industry should have hit its first milestone of a 10% emissions decrease, as detailed in the North Sea Transition Deal (NSTD), a collaborative agreement inked with government in 2021. That is just the first landmark on a much longer journey though, and by 2027 that required reduction rises to 25%, followed by 50% by 2030, before the North Sea becomes a net zero basin by 2050. To hit these demanding targets many offshore oil and gas assets will need to switch their power source - for many that will mean electrification. Industry regulator the North Sea Transition Authority (NSTA) kicked off a consultation in October with the aim of expediting the electrification of the UK’s upstream sector. This welcome and proactive move was accompanied by a clear warning for operators: lay out your plans for electrifying your assets or run the risk of further production approvals being knocked back. The consultation will close at the end of November, and we hope this will still be the message once all the responses have been collated. At Cerulean Winds we have always made our position clear - North Sea oil and gas production is not incompatible with net zero by 2050; rather it is a requirement

www.ogv.energy I November 2023

Mark Dixon, Co-Founder and Director, Cerulean Winds

for a managed and orderly transition. But decarbonising the North Sea hinges on the creation of a green energy infrastructure backbone. Our proposed basin-wide solution – the North Sea Renewables Grid - will be pivotal to achieving this.

Through the INTOG leasing process the

The events of the last two years have starkly demonstrated what can happen when energy security is neglected. Attention must be given to all three facets of the energy trilemma, something that requires the oil and gas industry to make good on its emissions reduction commitments.

floating wind farm capable of generating

It is understandable that, especially in the wake of the launch of the NSTA consultation, concerns have been raised about the financial and engineering challenges of platform electrification. There is no doubt that it’s a complex undertaking, but it is also an essential one. Companies should not drag their feet on this because the longer it takes to get these types of projects up and running, the more difficult it will become. Operators making firm commitments around decarbonisation is worth little though if they are unable to access affordable and reliable green energy. Here, the onus falls on offshore wind developers, especially those tailoring their projects for oil and gas decarbonisation, to hit their published targets.

Scottish Government approved 5GW worth of offshore wind projects, specifically focussed on North Sea platform electrification. Cerulean secured three lease options that will house the North Sea Renewables Grid, a sprawling multiple gigawatts of clean energy. Oil and gas assets will be able to access this green power generation and transmission system like they do onshore, offering a much-needed avenue to eliminate emissions. There will be large-scale economic benefit for the UK too, in the form of billions of pounds of investment and thousands of jobs. Cerulean is working toward a start-up date of 2028 for the North Sea Renewables Grid to meet, and possibly better, the 2030 emissions reduction targets, while also reaching assets that are farthest offshore. However, there are specific levers that offshore wind developers are unable to pull, and a large degree of risk attached to every investment decision. But with government, regulators and industry now starting to pull in the same direction there can be cause for optimism that we’ll start to see real progress on this soon. x

For information about membership, upcoming events or to join, please visit www.renewableuk.co.uk

RENEWABLES

CCUS to play a critical role in meeting global net zero targets By Jason Hendry, director of Aberdeen Renewable Energy Group (AREG) and managing director for England and renewables strategy, Peterson Energy Logistics

CCS has never been more positive. It also highlights the capacity for CCS projects in development globally has increased by 44 percent over the previous 12 months. In 2017 the UK Government set out a new approach to CCUS in its Clean Growth Strategy, which was designed to make the UK a global technology leader for CCUS. The current ambition to capture and store 2030Mt of carbon emissions per year by 2030, supports its overall goal of reaching net zero by 2050. As part of the 2023 Spring Budget, the government announced a £20bn investment in CCUS scale-up projects across the UK over the next 20 years. In July, the Acorn project in the North East of Scotland and the Viking project in the Humber were selected as CCUS clusters. Alongside Hynet in North West England and North Wales and the East Coast Cluster in Teeside and Humber, it is estimated these four clusters will support up to 50,000 jobs in the UK by 2050. A recent Arup report also outlined the “high value” opportunities within the CCS supply chain, which it says the UK is well placed to capitalise on due to its geology and strength in North Sea energy. As well as accelerating the decarbonisation of our industrial and power sectors, CCUS has the potential to create thousands of jobs and support the UK economy.

Jason Hendry

By 2050, the UK is legally required to reduce its greenhouse gas emissions by 100% from 1990 levels and a vital component of this ‘net zero’ target will be the development of Carbon Capture and Storage (CCS) technologies. The emission reduction technology has been identified as a ‘critical’ part of our net zero goals by The International Energy Agency (IEA), and the Intergovernmental Panel on Climate Change (IPCC) agrees that CCS is a key part of meeting targets for greenhouse gas emissions set out in the Paris Agreement. It’s not just fossil fuels that emit carbon dioxide (CO2), industries such as steel, cement, refining chemicals, glass, and ceramics all release the gas as part of their production, and although reducing emissions and switching to alternative sources of power, such as wind, solar, tidal stream, wave, biomass, geothermal, is most important, this won’t be enough on its own to limit global temperatures to 1.5C.

CCS, supported by technologies such as Direct Air Capture (DAC), can help reduce emissions from industries that are difficult to decarbonise by capturing CO2 and transporting it from where it was produced, via ship or pipeline, and storing it deep underground in geological formations or under the ocean. In addition to reducing emissions, a related concept known as Carbon Capture, Utilisation, and Storage (CCUS) allows for the re-use of carbon, converting it into, for example, low-carbon hydrogen and biomethane. This contributes to a more resilient supply of energy, and supports the energy mix of wind, wave, solar, etc, on days when there is a lack of these natural resources. We know that CCS works with projects operating in several countries including the UK. According to the Global Status of CCS Report, there were 194 large-scale CCS facilities globally in 2022 and the outlook for

There is, however, a long way to go. The UK Government estimates the need to raise £15bn in private investment just to construct and deliver the early stages of CCUS transport and storage assets. In addition to cost challenges, there are technical difficulties, safety, storage capacity, and regulatory requirements as well as public perceptions to overcome. With the backdrop of the climate emergency and the need for energy security and affordability now, whilst working towards a greener future powered by renewables, we must act now, moving forward with all proven methods for emission reduction from hardto-abate sectors. AREG supports all forms of renewable energy and technologies to reduce emissions and as part of its Energy Futures series of events, it plans to host a CCUS focussed webinar in 2024 to explore current and future projects and opportunities for its members across the supply chain. 

To stay up to date with AREG events and find out more about membership, contact info@aberdeenrenewables.com

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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.

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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.

SLB, Aker Solutions and Subsea7 announce closing of the OneSubsea joint venture

Subsea7 today announced the final closing of the previously announced joint venture with SLB1 and Aker Solutions2. The new business, which will adopt the OneSubsea name, will drive innovation and efficiency in subsea production by helping customers unlock reserves and reduce cycle time. OneSubsea now comprises SLB’s and Aker Solutions’ subsea businesses, which include an extensive complementary subsea production and processing technology portfolio, worldclass manufacturing scale and capacity, access to industry-leading reservoir and digital domain expertise, unique pore-to-process integration capabilities and strengthened R&D capabilities. OneSubsea’s field-proven subsea processing capabilities are seen by its customers as unparalleled in enhancing reservoir recovery and enabling long tie backs. Its unique compression technology portfolio has proven its potential to reduce the structure and capital cost of developing new energy reserves, while subsea projects have shown to be inherently more carbon efficient than topside solutions. OneSubsea will be headquartered in Oslo, Norway, and Houston, Texas, with 11,000 people working in all key operating regions around the world. SLB holds a 70 percent equity stake in the joint venture, with Aker Solutions holding 20 percent. Subsea7 holds 10 percent of the joint venture, in exchange for a cash consideration of USD 306.5 million paid in two equal instalments in 2023 and 2024.

www.ogv.energy I November 2023

TechnipFMC lands new contract with Petrobras

Mads Hjelmeland, CEO of OneSubsea said “OneSubsea’s extensive technology portfolio and engineering expertise enable us to address future market trends and needs at a unique scale. In doing so, we aim to fulfil our purpose of expanding the frontiers of subsea to drive a sustainable energy future. We will accelerate innovation and contribute to the ambition of our customers to optimize their production and reduce emissions in their subsea operations.” John Evans, CEO of Subsea7 said “Subsea7 is in the early stages of a prolonged upcycle driven by the continued growth of the world’s energy demand, combined with compelling competitive dynamics of the subsea industry. Our market-leading position is reinforced by the partnership with SLB and Aker Solutions in the OneSubsea joint venture and through Subsea Integration Alliance. We look forward to deepening the relationship with our clients as we work together to optimise value creation and deliver the lower-carbon energy the world needs.” Olivier Le Peuch, CEO of SLB said “The offshore market is demonstrating a sustained resurgence as operators across the world look to accelerate development cycle times and increase the productivity of their offshore assets. With its combined technology portfolio that leverages digital innovation, OneSubsea is ideally placed to support customers in their drive to improve asset performance while increasing energy efficiency and reducing CO2 emissions.”

Subsea giant TechnipFMC has been awarded a contract by Petrobras to supply flexible pipes for the pre-salt fields offshore Brazil. The New York-listed company will design, engineer, and manufacture 14 km of gas injection riser pipes and also supply associated services including packing and storage. “We have an established team in place who have earned the trust of Petrobras over many years of collaboration,” said Jonathan Landes, president of subsea at TechnipFMC. Earlier this year, TechnipFMC won a contract worth up to $500m to provide life-of-field services to Brazil’s statecontrolled firm. The new deal is worth between $75m and $250m. 

CONTRACTS TWMA to double Middle East operations following $100million contract win

more 400 personnel to support the work. The contract is the company’s largest in the region and will allow TWMA to upgrade its UAE office to support its growing operations across the Middle East. TWMA will handle, process and recycle all drilling waste generated from the site. Adhering to the nation’s in-county value programme (ICV), 90% of the manufacturing and fabrication work for the project will take place in Abu Dhabi. Pierre-Marie Hinden, UAE General Manager at TWMA said: “This is a game-changing contract for the company and is a testament to our commitment to driving in-country value for the operators we support in the Middle East.

Specialist drilling waste management company TWMA has secured a $100 million contract for a major sour gas development in Abu Dhabi. TWMA will deploy its award-winning RotoMill® solution alongside its newly launched XLink™ cloud based real time monitoring technology across four artificial island drilling units to promote efficiency whilst minimising the project’s carbon footprint. The five-year contract is a major milestone in the growth of TWMA’s UAE operations, with the company set to double its regional headcount to

“Having been operational in the UAE for more than 10 years, this win is evidence of the hard work and persistence that our dedicated team has exhibited in recent years. I look forward to seeing what future opportunities there are in store for our growing in-country team.” Gareth Innes, Chief Engineering and Commercial Officer at TWMA said: “This transformative award win underpins our growth plans for the Middle East and further cements TWMA’s reputation globally. “The client has recognised TWMA’s dedication to ensuring clean and safe waste management solutions. This showcases our devotedness to promoting environmentally conscious practices across all our operations. I am incredibly proud of the growth and opportunities which our UAE team has achieved through winning this significant contract.” 

Elemental Energies secures major wells decommissioning project from Archer Leading independent wells expert, Elemental Energies, has secured a contract estimated at £10 million with Archer, a provider of drilling, Plug and Abandonment (P&A), and well services to the global energy industry, to support a major decommissioning project, in the UK North Sea. This award will see Elemental Energies expand their already significant inhouse P&A team, with a further 10 roles being added. The agreement between the wells specialist and Archer will see it provide complete abandonment engineering and operational support across multiple platform wells over the next three years. Within the strategic partnership, a multidisciplinary team of onshore and offshore engineers from Elemental Energies will work alongside Archer to lead the detailed abandonment planning and support the operational activity. Work is underway on the first phase of the project which will involve wireline investigative work followed by a coiled tubing campaign. Engineering of the P&A operations has also started which are set to commence second half in 2024 or early 2025 upon completion of platform preparation scopes. Kenny Dey, Archer UK’s Managing Director, said: “The combined capability and experience of the Archer and Elemental Energies engineering team is raising the bar for decommissioning projects of this scale and we are pleased to be working in partnership with their expert well engineering, operational and project management teams to deliver this major project.” Mike Adams, Chief Executive Officer, of Elemental Energies, said: “Our collaboration with Archer is an important milestone as we build on our extensive experience within well decommissioning. By embedding our engineering expertise within Archer we will maximise efficiencies and mitigate risks earlier in the planning and operational phases of the project. “Efficient and expertly planned well P&A is a cornerstone for successful decommissioning globally and is a critical part of reducing long term emissions from wells. We are passionate about the role that

decommissioning plays in the energy transition, and we are proud to be delivering that alongside our partner Archer.” With over 500 wells abandoned since 1989, Elemental Energies are committed to helping the industry expertly manage the challenges of decommissioning legacy infrastructure, with key partners being pivotal to past and future success. Following the acquisition of Vysus Senergy Wells, Elemental Energies acquired Norwell Engineering in May 2023 and is expected to announce further acquisitions over the coming 18 months. Elemental Energies is committed to supporting the global energy transition by providing worldleading technical capabilities, placing well engineering at the heart of upstream, decommissioning, and low carbon projects. 

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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.

Fulmar Field Decommissioning, North Sea, UK

Fulmar is an offshore oil field in the North Seam operated by Repsol Sinopec. Development of the field began in 1978, while the installation of the Fulmar complex was completed in 1981. Oil production from the Fulmar field commenced with the first oil from the Fulmar Advanced Drilling (AD) wellhead jacket in February 1982. Oil production from the Fulmar Alpha (A) platform followed in May 1982. Production from the field ceased in October 2018, as approved by the North Sea Transition Authority (formerly the Oil and Gas Authority). The plug and abandonment (P&A) works are expected to commence in late 2024 to early 2025. Production at the Fulmar platform reached more than 130,000 stock tank barrels per day in its peak production years, between 1988 and 1989. The Fulmar field produced 565 million metric barrels of oil (Mmbbls) during its operational life, significantly contributing to the UK economy.

Location The Fulmar field is located 312km east of Dundee, Scotland, and 12km northeast of the Auk oilfield in Blocks 30/16 and 30/11b in the Central North Sea at water depths of 83m.

Fulmar field infrastructure The Fulmar field installation consists of two bridge-linked jacket structures that house drilling, production and accommodation facilities.

www.ogv.energy I November 2023

Fulmar A is the main production platform, mounted on a large steel jacket with eight legs. It has 36 wells, while the Fulmar AD wellhead platform has six. Fulmar A weighs approximately 12,400t, while the four-legged fixed steel jacket platform, Fulmar AD, weighs 1,406t. Oil from the field was initially exported by tankers via a floating storage unit (FSU) connected to a single anchor leg mooring (SALM) base. A second SALM base was installed due to the FSU breaking free in December 1988. The transport of oil products from the field was, however, changed in 1997 to use the Norpipe system, which connects to the Teesside oil terminal at Seal Sands in Middlesborough. The SALM bases have not been utilised since then. The Fulmar field provided transportation and redelivery services for the Gannet, Auk, Clyde, Orion and Flyndre fields from the Fulmar platform via the Norpipe system. The platform also processed oil from the Halley field and the Auk North sub-sea tieback.

Fulmar field decommissioning details The decommissioning of the Fulmar field will involve jacket removal, onshore dismantling, recycling and disposal of topsides and associated substructures. It will be a fully integrated P&A project with a modular P&A rig, well services and well engineering.

The decommissioning activities will include the removal of surface facilities installations including the Fulmar A production platform, the Fulmar bridge link, and the Fulmar AD wellhead platform. The sacrificial anodes protecting the jackets will remain in situ. The Fulmar platform will continue operating as an export hub for Auk, Clyde and Gannet until the fields cease production or bypass Fulmar. The plugging and abandonment of the platform wells in Fulmar are expected to be completed during this waiting period to minimise abandonment support costs. The topsides will be fully decommissioned once all platform wells are plugged and abandoned, and the platform ceases to operate as an export hub. The topsides will be transported ashore for dismantling and cleaning of reusable equipment. Recycling and disposal work will be carried out for equipment that cannot be reused. The subsea infrastructure will be decommissioned post-removal of the Fulmar topsides. A survey of the pipelines and umbilicals will be carried out to determine whether to remove or leave them in situ.  READ MORE DECOMMISSIONING NEWS ON OUR WEBSITE WWW.OGV.ENERGY x

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DEA seeks feedback on North Sea Ravn decommissioning submission

The Danish Energy Agency (DEA) has made available Wintershall Nordzee’s environmental impact report for decommissioning of the Ravn Field in the Danish North Sea. This will be Denmark’s first experience of a full decommissioning of an oil and gas field. The public, including Danish authorities and organizations, have until Dec. 1, 2023, to submit comments and questions to the DEA. Ravn’s platform and associated installations were constructed in 2015 and are in permits 5/06 and 2/16, 245 km from the Danish coast and 15 km from the German offshore median line. The platform is connected to two subsea pipelines and a supply

line linked to the A6-A platform in the German sector. Two suspended production wells connected to the Ravn platform are no longer in service. Wintershall Nordzee has applied for permission to permanently shut in the wells, subject to an independent environmental assessment, prior to decommissioning of the platform. In addition, Denmark has undertaken to remove installations in its sector of

the North Sea built for the extraction and transport of oil and gas. This means the platform and associated installations must be dismantled and removed to be transported ashore for scrapping or recycling. Pipelines are not subject to this obligation, so the DEA must assess whether they should be decommissioned in-situ following cleaning, or removed and transported ashore. 

Petrofac, Saipem Bag Multimillion Deal for UK Platform Decommissioning Petrofac Inc. and Saipem SpA have secured a contract to support the decommissioning of a platform in the United Kingdom (UK) sector of the North Sea. Under the terms of the contract, the two companies will work as an integrated team to prepare and remove the 20,000-metric-ton topside using the Saipem 7000, one of the largest semi-submersible heavy lifting vessels in the world, Petrofac said in a news release Monday. The contract details were not disclosed, although the energy service provider said the contract was a “multimillion pound” deal.

a safe and predictable program that can serve as a case study for the North Sea’s transition”. Further, Petrofac has been awarded a three-year contract extension in support of Repsol Sinopec Resources UK’s North Sea operations worth over $100 million. The contract is for the provision of operations and maintenance services, Petrofac said in an earlier news release. Since Petrofac’s initial appointment by Repsol Sinopec in 2016, the scope of work has grown steadily, with Petrofac securing contracts for an additional six North Sea assets in 2020, according to the release.

Petrofac said it will execute the three-year project over two phases. The first phase will be for preparations onboard the platform, while the second will be on the Saipem 7000 for the actual removal campaign. The scope of Petrofac’s contract includes module separation, lift point inspection, lift point installation, riser, and caisson severing.

“Our relationship with Repsol Sinopec has continued to grow, adapting to new requirements and the operating environment”, Shorten said. “This contract extension demonstrates our team’s commitment and drive to support Repsol Sinopec through safe and effective operations. We look forward to our continued partnership and collaboration across their North Sea assets”.

“As our sector pursues cleaner sources of energy, decommissioning is a key enabler for the transition”, Petrofac Asset Solutions COO Nick Shorten said. “Supporting Saipem and their customer, we look forward to leveraging our knowledge of North Sea operations and service provision, and 20 years of decommissioning experience to deliver

The contract includes servicing for a range of assets, including Arbroath, Auk, Bleo Holm, Claymore, Clyde, Fulmar, Montrose, Piper, Saltire and Tartan assets in the North Sea. Petrofac also provides support to Flotta Oil Terminal and Nigg Oil Terminal. 

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STATS & ANALYTICS

Offshore Field Development Update Offshore O&G-related engineering, procurement and construction (EPC) contract award value year-to-date is estimated at US$31 billion, excluding letters of intent (LoI). This represents US$3.6 billion of EPC contract award value recorded over the last 30 days. This was driven by the final investment decision (FID) and contract award for ADNOC’s Hail and Ghasha project offshore the UAE, with a joint venture of NPCC and Saipem responsible for the four drilling centres and one processing plant to be built on artificial islands, as well as various offshore structures and more than 300 km of subsea pipelines, with a total contract value of US$4.1 billion. It is pertinent to state that only the estimated contract value associated with the offshore structures and associated subsea pipelines is included in Westwood’s recorded EPC spend. During the period under review, Equinor announced an FID on its long-delayed Rosebank project, with the first phase of the project requiring a total investment of US$3.8 billion. Following the FID announcement, TechnipFMC confirmed an integrated engineering, procurement, construction and installation (iEPCI) contract award valued at approximately US$500 million for subsea production systems, umbilicals, risers and flowlines. The contractor confirmed that the award will be recorded in its 1Q 2023 inbound orders. In addition, Altera Infrastructure’s Petrojarl Knarr FPSO had its bareboat charter, operations and maintenance contract confirmed for a firm period of nine years, with options up to a total of 25 years. The unit arrived at Drydocks World shipyard, Dubai, in August 2023 for the FPSO upgrade work scope. Equinor also confirmed that development drilling will commence in 2Q 2025. Looking forward, Westwood forecasts an additional US$25.6 billion of offshore O&Grelated EPC spend for the remainder of 2023, driven predominantly by brownfield expansion projects in the Middle East such as Saudi Aramco’s CRPO 97 and CRPOs 104 to 113, with an estimated EPC award value of over US$8 billion. Furthermore, projects such as QatarEnergy’s North Field Expansion Phase II, Idd El Shargi North Dome (ISND) – Phase V project, and North Oil Company (NOC)’s Ruya project are currently anticipated to have related offshore EPC contracts awarded before the end of 2023. Outside the Middle East, TotalEnergies’ Cameia and Golfinho project (Angola), Azule Energy’s Ndungu (Angola) and Eni’s Structure A & E project (Libya) could potentially drive estimated EPC award value for the remainder of the year. Offshore Drilling Rig Update The global committed jackup count averaged 408 units in September. The marketed available and cold-stacked jackup counts now stand at 30 and 56, respectively, while marketed committed utilisation and total utilisation were 93% and 83%, respectively. During the month, a total of 14 contracts were awarded and six options were exercised, amounting to 9,290 days (25.5 rig years) of backlog added. BP has exercised five one-well priced options on Valaris 106 with direct commencement of its current programme, keeping it engaged until mid-2025. The global committed semisubmersible count came in at 68 during September. There are 10 available and 16 cold-stacked rigs remaining in the fleet. Marketed and total utilisation dropped to 87% and 72% during the month, respectively. Three new contracts were awarded in August, one of which was awarded to Kan Tan III by CNOOC on a three-year programme off China. Finally, the drillship count decreased by one unit to 81 during the month, leaving three marketed units available plus 12 cold-stacked units. Marketed committed and total utilisation remained at 96% and 84%, respectively. Two new contracts were awarded, where Valaris DS-15 will be drilling for BP off Brazil for 90 days at a dayrate of $410,000. Offshore Wind Update Since the last update, Vestas signed two firm contracts for the supply of its V236-15.0 MW turbine. Vestas will supply a total of 64 turbines to the 960 MW He Dreiht wind farm, located offshore Germany and 76 turbines to the 1,140 MW Baltic Power wind farm, located offshore Poland. The two contracts include Active Output Management 5000 (AOM 5000) service agreements. Dominating headlines was news that no offshore wind capacity was awarded in the UK's fifth Contract for Difference (CfD) allocation round. This is a stark departure from last year's round, where 7 GW of offshore wind projects received CfDs. The deterrent for many developers this year was the lower maximum bid price of GBP 44/ MWh, as opposed to last year's GBP 46/MWh despite ongoing inflation and supply chain challenges. Finally, the capacity of the UK's Celtic Sea floating wind leasing round has been increased from 4 GW to 4.5 GW by The Crown Estate. A total of three 1.5 GW Project Development Areas (PDAs) will now be available in this lease round. The Crown Estate has also stated that no bidder will be able to secure an agreement to lease in more than one PDA. An Information Memorandum is expected to be published before the end of 2023 ahead of the formal start of the leasing round. 

www.ogv.energy I November 2023

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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.

www.westwoodenergy.com

Offshore Energy Services Dashboard October 2023

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HUGH FRASER INTERNATIONAL

Why should businesses go global. If you look at the question of developing internationally, particularly from a North Sea origin point of view we have to be realistic and accept that the best of the growth opportunities are behind us. Therefore, to sustain and grow businesses the international dimension is absolutely imperative. I also think internationalising a business drives a management team, it drives the people, it drives the technology, it drives the systems to a new higher level. I think a business which has an international dimension to it is going to have a much higher chance of succeeding to higher levels. It just raises the bar, it raises the game for everyone involved in that business.

We see expansion opportunities coming from two directions, first of all as we move from our traditional support of advanced petroleum technology businesses we see a lot of opportunities in the energy transition technology businesses on one route. Secondly, we see a geographical opportunity: We do have joint ventures moving forward this year for India and Egypt, the wider Egypt, north Africa, Mediterranean covering the east and the west flanks of the Middle East. We also see opportunities for growth in the Caspian and central Asian direction to the north and the east African direction. 

HFI is a specialist professional services firm led by Hugh Fraser, a Scottish corporate/energy lawyer with over 30 years’ experience in the international energy sector. We support clients to establish, expand and divest their international businesses through strategic, value-added consulting and legal services, combining specialist know-how, connections, local partners and execution expertise. Our focus is on ventures which combine advanced energy technology and know-how with opportunities in the key territories of the Middle East region including joint ventures, acquisitions and divestments.

Adjudication in decommissioning-

could it be the future of dispute resolution? Christopher Duff, Partner, Brodies LLP

Adjudication has established itself as the pre-eminent method of resolving disputes in the construction sector over the last 25 years. Parties to a construction contract can refer disputes to an adjudicator at any time whose decision is binding unless and until the dispute is subsequently determined by further legal proceedings or resolved by agreement.

That the need to have the right answer has been subordinated to the need to receive the answer quickly. The process can therefore be rougher and readier than litigation or arbitration.

Adjudication offers an established and efficient dispute mechanism for parties to construction projects, and it's a method of dispute resolution that could now gain some traction within the decommissioning sector. The two primary standard form decommissioning contracts, LOGIC's General Conditions of Contract for Offshore Decommissioning (2018), and BIMCO's Dismantlecon (2019) both include adjudication clauses which provides a level of support and awareness in the market.

That parties must comply with an adjudicator's decision unless and until the parties receive a final determination from the courts or at arbitration.

Expertise To build on that support, those managing and advising on contracts and disputes will need a working knowledge of the adjudication process. Likewise, a pool of capable adjudicators expert in their subject matter will be required. The good news is that there is a substantial body of caselaw which can help guide parties navigate the process. Some key points from the last two decades of adjudication in the construction industry include:

www.ogv.energy I November 2023

That adjudicators' decisions will be enforced by the UK courts. Only in rare cases are decisions not enforced, and on well understood principles. That adjudication is suitable for a range of disputes. High value and/or complex disputes are routinely referred. Confidence Despite being initially introduced as a process to encourage parties to 'pay now, argue later' adjudication has enjoyed the confidence of the market because it has proved far more adaptable and successful. Adaptable because it has never confined itself to simple payment disputes. Many quality control, completion, variation claims or professional liability disputes are adjudicated. There is therefore an array of technical specialists in differing disciplines acting as adjudicators.

www.hfi-consulting.com

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And successful, because very rarely do parties now 'argue later'. In their excellent paper, '2022 Construction Adjudication in the United Kingdom: Tracing trends and guiding reform', published by the Centre for Construction Law & Dispute Resolution, King's College London (in collaboration with the Adjudication Society), reported that 42% of respondents said that in fewer than 5% of their adjudications, the parties sought a final determination by the courts or at arbitration. The appeal of the specialist dispute resolver has been a key driver of its success; as has the cost and speed of the process. With all of this in mind, within the construction sector, resolving disputes using adjudication is no longer regarded as an alternative dispute resolution process, but rather the dispute resolution process. Within the decommissioning sector, adjudication is in contrast, relatively new to the market and one of several dispute resolution methods vying for priority. The advent and development of DABs and the popularity of arbitration (especially for cross-border disputes) present obvious competition. Nonetheless, if decommissioning is in certain respects construction in reverse (and with some of the same attendant issues), that suggests there should be a market for a quick and effective method of resolving disputes. And that is where adjudication can play a bigger part. Christopher is based in Brodies' Aberdeen office, visit brodies.com for more information.x

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UPCOMING GLOBAL EVENTS 2023

Europort 2023 7-10 November 2023 Rotterdam, Netherlands

Offshore Wind North East 2023 (OWNE) 8-9 November 2023 Sunderland, UK Electricity North Africa 2023 13-15 November 2023 Mohammadia, Algeria Hassi Messaoud Expo 2023 15-17 November 2023 Hassi Messaud, Algeria Electric Power Automation show (EPA) 2023 15-17 November 2023 Shanghai, China Smart Grid Expo Osaka 2023 15-17 November 2023 Osaka, Japan PV System Expo Osaka 2023 15-17 November 2023 Osaka, Japan World Smart Energy Week Osaka 2023 15-17 November 2023 Osaka, Japan

Myanenergy 2023 16-18 November 2023 Yangon, Myanmar

The Global EPC Project Management Forum 27-30 November 2023 Amsterdam, Netherlands The Global Big Data Analytics In Power & Utilities Industry Forum 27-29 November 2023 Amsterdam, Netherlands World Nuclear Exhibition 2023 28-30 November 2023 Paris, France

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