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• 
  PPP offers budget and efficiency routes

  7 May 2024

  

   

  The procurement of the multi-utility packages for the Red Sea and Amaala developments, as well as for the staff accommodation packages at Neom, will use a public-private partnership (PPP) model, opening up an alternative route for Saudi Arabia to finance and ensure the efficiency of its gigaprojects.

  In the case of the Red Sea and Amaala schemes, bundling the utility elements of these greenfield projects – including renewable energy generation, cooling, water desalination and treatment and waste recycling – makes sense for both the procuring entity and the utility developers and investors.

  Instead of dealing with several developers or suppliers, the client – which does not necessarily specialise in providing utility services – only has to deal with the selected developer, which then manages the contractors and operations and maintenance companies.

  Complex infrastructure takes a long time to procure. This is a fact, particularly when quality is a focal point"

  Cost and operational efficiencies are also incentives, given that each component of the project is relatively small and may require a bigger budget if they were to be procured as separate contracts.

  PPPs serve both as a solution and challenge to perceived budget and liquidity issues that are facing the official gigaprojects as they enter the execution phase, not to mention their tight delivery timelines.

  Neom, for instance, is pursuing both PPP and conventional procurement models for the renewable energy and water desalination facilities it requires for the SR1.9tn ($500bn) development.

  “Complex infrastructure takes a long time to procure. This is a fact, particularly when quality is a focal point," note Jason Gouveia and Joanna McGuire, senior associates at UK-headquartered legal consultancy Ashurst. 

  "There will, therefore, always exist a natural tension between urgency and procurement duration in the context of PPP deals, and it is important to keep a tight handle on the efficiency of the procurement process.”

  This requires procurers and their advisers to carry out feasibility assessments before going to market, and to address any issues that bidders and their lenders are likely to raise as part of their due diligence on a PPP project, they add.

  The kingdom's gigaprojects are contending with 200 other infrastructure schemes that are being planned by various ministries through the National Centre for Privatisation & PPP (NCP), the state PPP procuring authority.

  Among the schemes in the NCP’s pipeline are airports, seaports, roads and healthcare facilities, which all cater to Saudi Arabia’s growing infrastructure needs as the population and economy expand.

  This pipeline will only grow, as it is anticipated that the procurement models for some aspects of the gigaprojects will be changed in response to budgetary cuts, and more lenient execution timelines may also be adopted, potentially extending the deadlines from 2030 to 2040.

  Liquidity squeeze

  Some experts cite the overall liquidity of local banks and the willingness of international lenders to participate in future projects in response to the growing PPP pipeline.

  “The liquidity levels of local banks are not readily ascertainable. However, given the rate of progress on projects within the kingdom, which assumes committed financing is in place, it seems that local banks, together with the support of their international counterparts and institutional investors, are able to meet the liquidity demands of projects,” say Gouveia and McGuire.

  The pair adds that an efficient, robust and safe monetary policy is key to attracting international banks to the Saudi PPP market.

  “On the projects we are advising on, international lenders and development investment funds are a common feature, as the international lending market seeks to diversify their books of debt.

  “Depending on the complexity and capital intensity of a PPP project, there may be no other option but for the lending market to be a syndication of local and international lenders, to ensure that capital requirements are met.”

  Lenders are also most likely to target the more lucrative projects – such as the gigaprojects and those schemes initiated by the Saudi sovereign wealth vehicle, the Public Investment Fund (PIF) – over others in the PPP ecosystem.

  “Given that the capacity of the market is naturally limited in terms of resourcing, there is a potential danger that the NCP's PPP programme may find itself suffering in comparison to those other market segments,” the two lawyers warn.

  A senior PPP transaction expert does not entirely agree, noting that PPPs account for only a small percentage of the pipeline of gigaprojects.

  The impact of the budget shift and the scope for the gigaprojects to move parts of their projects to a PPP model remains limited.

  He agrees, however, that developers do tend to prefer to be associated with the gigaprojects over the NCP projects.

  Within the gigaprojects sphere, concerns about who ultimately bears the payment risk in a PPP project become relevant. Ashurst’s Gouveia and McGuire say it is always preferable for the entity with the greater financial wherewithal to bear the burden of payment.

  "Often, there may be certain governmental-level letters of comfort or support provided by the finance ministry that are added as a supplementary means of payment protections and credit support," they explain.

  

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  MEED's April 2024 special report on Saudi Arabia includes:

  > GVT & ECONOMY: Saudi Arabia seeks diversification amid regional tensions
  > BANKING: Saudi lenders gear up for corporate growth
  > UPSTREAM: Aramco spending drawdown to jolt oil projects
  > DOWNSTREAM: Master Gas System spending stimulates Saudi downstream sector
  > POWER: Riyadh to sustain power spending
  > WATER: Growth inevitable for the Saudi water sector
  > CONSTRUCTION: Saudi gigaprojects propel construction sector
  > TRANSPORT: Saudi Arabia’s transport sector offers prospects

   

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  Jennifer Aguinaldo
• 
  Decarbonising the global energy grid

  3 May 2024

  As the effort to tackle the climate crisis continues, global demand for renewable energy has been increasing. Unfortunately, the windiest and sunniest parts of the world are not necessarily where the need for energy is highest. This is where transmission plays a big role, linking energy generation to energy use as a product of global interconnection, and diversifying production from renewable sources to create a steadier supply of clean power. 

  Transporting energy across vast distances is not easy though. From the regulatory complexities of navigating cross-border infrastructure projects to the high costs of financing and the need for long-term planning and advanced technical capabilities, the challenges involved in successfully deploying long-distance transmission projects are varied. Overcoming these challenges is not a single party affair, but requires close collaboration across government, industry and non-governmental organisations. 

  We conducted a study with nearly 600 industry experts from across the world who highlighted the pressing need for co-ordinated global action to rapidly develop grid infrastructure. Integrating renewable energy into existing grids was cited by participants as one of the most significant barriers to achieving net-zero objectives, alongside supply chain vulnerabilities and ability to access the required capital.

  Multiple challenges

  From a technical standpoint, there are multiple considerations when implementing cross-border interconnections. Regions can operate using different technical parameters, such as different voltages or frequencies. Even within the same country, interregional variations can create bottlenecks. Adopting regional or international grid codes could mitigate these issues.

  Further challenges emerge when we take trading into account. This is where regulation can act as an enabler, facilitating the flow of electricity between countries. The European Union’s efforts to co-ordinate the design of its member state’s energy markets enables an increasingly smooth transmission of energy across the continent. Alongside this, existing infrastructure is outdated, requiring significant upfront investment to upgrade. Clarity on regulatory requirements and more transparency around plans for grid buildout, derisk funding for capital-intensive mega projects.

  Coordinated action is vital for the transfer of energy across borders and access to renewable sources of energy

  Positive benefits

  Despite these challenges, the upside must be stressed. Integrating power systems across borders has many positive societal benefits, decreasing costs and hence energy bills through economies of scale, increasing energy security and lowering the environmental impact of operations. On the latter more specifically, larger power systems are able to integrate higher shares of variable renewables. Globally, the sun is always shining and the wind blowing somewhere. 

  A common element, therefore, emerges: the need for increased cross-border co‑ordination. Whether it is bilateral, multi-lateral or unified, different models of inter-jurisdictional arrangements are needed for large-scale projects to support global energy interconnections. Our Xlinks project, which is using high-voltage direct current (HVDC) for transmission, is a standout example. 

  Such projects represent what is needed more in the world, the combination of infrastructure and renewable power across borders, bringing together the public and private sectors for energy security, supply and affordability in an environmentally friendly way. Transporting clean energy using HDVC cables is a crucial step in powering a net-zero and equitable future, and more of this is needed to aid the transition to lower-carbon and prosperous economies. 

  Political, technical and market hurdles can be overcome through collaboration and partnerships. Leveraging the collective expertise and resources of governments, regulators and the private sector can help ensure interconnections are developed quickly enough to support the energy transition. Grid buildout takes time. We have the resources required to meet ambitions, but stopping now is not viable. We must continue planning, building and maintaining large-scale infrastructure projects to meet the rising demand.

  Coordinated action is vital for the transfer of energy across borders and access to renewable sources of energy. This was the message from Cop28 and the UAE Consensus: to help progress and secure a cleaner, brighter future for us all, we must break down barriers and come together. 

   

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• 
  Libya allocates $1.2bn for upstream oil project

  3 May 2024

  

   

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  Libya has allocated LD6bn ($1.23bn) to develop the Hamada NC-7 concession in its latest budget, which was approved by Libya’s eastern-based parliament on 30 April, according to industry sources.

  The field development project was previously estimated to be worth between $4bn and $5bn.

  The project aims to develop 2.7 trillion cubic feet of gas reserves in the NC-7 block of the Ghadames basin.

  A consortium led by Italy’s Eni and including France’s TotalEnergies and UAE-based Adnoc operates the block.

  Development of the field was included in the 2024 annual budget of LD90bn ($18.5bn), excluding an item for development projects, which the Benghazi-based government of Osama Hamad unanimously approved.

  Hamad came to power in March 2023 and is allied with the military commander Khalifa Haftar, who controls the east and large parts of the southern region of Libya.

  Progress on developing the Hamada NC-7 concession has been slow amid concerns among politicians about the involvement of foreign oil companies in key hydrocarbon assets.

  On 15 December 2023, the Tripoli-based Ministry of Oil & Gas issued a statement condemning the terms of the planned gas development contract between Libya’s state-owned National Oil Corporation (NOC) and the consortium led by Eni.

  In the statement, the Ministry of Oil & Gas described the deal as a “violation of Libyan legislation on oil contracts”.

  Earlier this year, NOC announced a plan to execute 45 greenfield and brownfield projects to try to boost the country’s oil production from 1.25 million barrels a day (b/d) to 2 million b/d.

  Farhat Bengdara, the chairman of NOC, said that the projects had a total estimated cost of $17bn-$18bn.

  Bengdara also confirmed plans to launch an oil and gas licensing round at the end of 2024 or early 2025.

  Libya is aiming to hit its 2 million b/d target within three years.

  Bengdara said that gas monetisation will remain a strategic focus as the country pushes to increase exports to Europe.

  Libya is only using 25% of the capacity of its Greenstream pipeline to Italy.

  The North African country also flares significant volumes of natural gas and has 12 projects under way that aim to reduce gas flaring to almost zero, according to Bengdara.

  In recent years, Libya has struggled to execute large projects amid significant political instability.

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  Wil Crisp
• 
  GE Vernova invests in Xlinks

  2 May 2024

  US-headquartered GE Vernova has invested $10.2m in Xlinks First, the investment company established by UK-based startup Xlinks to deliver the $18bn Morocco-UK power project.

  This investment equates to a minority shareholding in the company, which is developing a project comprising wind and solar generation as well as battery storage, with a total combined capacity of 3,600MW, to be transmitted from Morocco to the UK.

  Xlinks said the investment will “further accelerate delivery and buildout of the project”.

  GE Vernova joins at least four other investors in the project.

  Other investors include Africa Finance Corporation, which invested $14.1m in April; Abu Dhabi National Energy Company (Taqa), $30.7m; the UK’s Octopus Energy, $6.23m; and France’s Total Energies, $25.4m.

  The planned electricity generation and battery storage facilities, located in south Morocco, will be connected exclusively to the UK via 4,000-kilometre high-voltage, direct current (HVDC) cables.

  In December last year, Xlinks signed a contract with Canada-headquartered WSP to provide technical advisory services for the project.

  WSP will support Xlinks with route optimisation, power systems and interface management for the plan to construct the project.

  The Morocco-UK power project entails building 10,500MW solar and wind farms in Morocco’s Guelmim-Oued Noun region and sending 3,600MW a day of energy exclusively to the UK via four 3,800-kilometre HVDC cables.

  The HVDC network is envisaged to run from the UK’s south coast, passing France, Spain and Portugal undersea and then onshore to a planned solar and wind energy project in Morocco.

  This renewable energy-sourced electricity amounts to nearly 8% of the UK’s current requirements, equivalent to powering 7 million homes by 2030.

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  Jennifer Aguinaldo
• 
  Awards buoy Oman’s green hydrogen strategy

  2 May 2024

  Commentary
  Jennifer Aguinaldo
  Energy & technology editor

  Oman has awarded two additional land blocks designed to develop green hydrogen projects.

  The latest land block concessions in Dhofar were awarded to two consortiums. One comprises a team of France's EDF Group and EDF Renewables, with partners Japanese Electric Power Development Company (J-Power) and the UK-headquartered Yamna Company.

  Another team comprises UK investment firm Actis and Australian metals firm Fortescue.

  This brings the total number of land blocks awarded through the public auction process spearheaded by Hydrogen Oman (Hydrom) to four, exclusive of the four legacy initiatives signed or agreed upon already.

  *Budgets are MEED estimates if not publicly disclosed. Sources: MEED, Hydrom

  A limited gas supply and network strongly incentivises Oman to build a green hydrogen-centric downstream sector that will provide feedstock to domestic industrial plants and generate derivatives for the local and export markets.

  Stakeholders have implemented a strategy, including setting up an infrastructure company catering to these projects. The target is to generate 1 to 1.5 million tonnes a year (t/y) of green hydrogen by 2030 and 7.5 to 8.5 million t/y by 2050.

  The blueprint envisages a complete green hydrogen ecosystem, from the production of renewable energy and its distribution to electrolysis plants and hydrogen derivatives conversion plants to storage and export terminals.

  Omani ports' existing relationships with European stakeholders and growing alliances with other countries could also help seal future offtake agreements for the planned facilities.

  As things stand, the consortiums that won the land auctions and the legacy initiative partners provide much gravitas to Oman's green hydrogen programme. They comprise energy old guards such as BP and Shell that are keen to decarbonise, private companies aiming to balance their investment portfolios with clean energy investments, and offtakers or trading companies that are grappling with net-zero targets.

  Yet the most obvious question remains. Given the eye-popping foreign direct investments these complex projects entail, not all are likely to achieve a final investment decision within three years. This seems to be the window required for the projects to start production before 2030.

  But like any emerging industry, the risks can only be properly assessed and mitigated as the first projects move toward the execution phase.

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  Jennifer Aguinaldo