Falck Renewables and Eni US sign an agreement to acquire 62 MW of operating wind and solar projects and up to 160 MW wind development pipeline in the United States
Falck Renewables and Eni New Energy US Inc, through Novis Renewables Holdings (Novis), a partnership with 51 per cent and 49 per cent shares respectively, signed an agreement with Building Energy to acquire Building Energy Holdings US (BEHUS).
BEHUS business consists of 62 MW of operating wind and solar projects in the US, a development and asset management team and a pipeline of wind projects up to 160 MW. A wholly owned subsidiary of Novis will acquire the equity of all the projects, the development assets, and the other activities of BEHUS upon the satisfaction of conditions precedent to the transaction for a total purchase price of $32.5 million that will be adjusted in line with market practice. The closing should be done by the end of the year.
BEHUS was founded by Building Energy S.p.A. to develop wind and solar projects in the US in 2013. Novis will acquire five operating solar projects totalling 31.59 MW and a 30 MW wind project in Iowa all of which sell power under Power Purchase Agreements. Falck Renewables North America will provide technical and administrative asset management on behalf of Novis to manage the newly acquired projects post-Closing of the transaction.
Novis will also acquire the development and operations team and a wind and solar development pipeline of BEHUS. Specifically, two late stage up to 80 MW each wind development projects in the western United States.
The generation for the assets in operations will contribute to offsetting over 93,000 tons of C02 per year.
“BEHUS is the inaugural transaction of the strategic partnership with Eni that closed in March 2020 and fits squarely into our joint business plan contributing to the sustainable growth targets of both partners”, commented Toni Volpe, CEO of Falck Renewables S.p.A, “we are also adding onshore wind both in operations and development to our portfolio in the USA strengthening our development and operations team”.
”For Eni, the acquisition of BEHUS is another step forward in our decarbonisation strategy, that is increasingly driving our company towards the development and production of energy from renewable sources,” stated Massimo Mondazzi, General Manager of Eni’s business group Energy Evolution.
“In Eni, we have set very clear targets for our activities, as we intend to reach 3 GW by 2023 and over 15 GW of installed capacity by 2030. Our emission targets are equally well defined, with an 80% cut in all our direct and indirect emissions by 2050,” he added.
McDermott International announced it has been awarded a contract by Delta Offshore Energy to provide front-end engineering design (FEED) services for a subsea gas pipeline in Vietnam.
The pipeline will connect a regassification platform, located approximately 22 miles (35 kilometers) offshore, to the planned 3,200 MW power plant in Bac Lieu Province, Vietnam.
McDermott also said in a statement that it has been awarded the pre-engineering geotechnical and geophysical survey services being carried out as a part of the FEED scope.
McDermott's Houston office is leading engineering services—supported by its Kuala Lumpur office. McDermott will perform project management, execution planning and estimation services. Installation studies will be performed by McDermott's marine operations.
"This award illustrates the confidence Delta Offshore Energy and its partners have in McDermott's ability to deliver a turn-key EPCI solution for the subsea gas pipeline FEED scope for its Sisyphus project," said Mark Coscio, senior vice president for North, Central and South America. "We look forward to expanding our partnership and achieving a successful outcome."
McDermott's extensive experience in Vietnam and recent work for Delta Offshore Energy were key factors for this contract win.
McDermott said it expects the FEED contract will be converted into an EPCI contract in the first quarter of 2021.
Fugro, in partnership with Solstad and Oceanpact, has been awarded three long-term contracts by Petrobras to provide remotely operated vehicle (ROV) services for a variety of subsea activities in Brazil.
All three contracts are for 3-year firm periods with additional 1-year options.
Fugro will provide a total of five work class ROVs for these contracts, each outfitted with tooling and survey spreads that are operational in water depths of up to 3000 m. One ROV spread will be installed on the Solstad AHTS Far Statesman to conduct anchor handling and other subsea support activities. The remaining ROV spreads will be deployed in pairs on two vessels operated by Oceanpact to perform inspection, repair and maintenance (IRM) services. Led by a team of local, highly skilled personnel, all ROV services will be available to Petrobras around-the-clock to maximise work capacity and ensure operational efficiency.
“These new contracts will nearly double Fugro’s IRM capacity in Brazil, helping us capture the increase in demand for these services by Petrobras,” said Rogerio Carvalho, Country Manager for Fugro in Brazil. “The associated mobilisation plans with our vessel partners will be challenging amid the concerns caused by the COVID-19 pandemic but, with proven protocols in place, we look forward to confirming Fugro’s leading position as a supplier of ROV services in the region.”
Global E&C is embarking on a major facility move as it consolidates it businesses and looks to evolve and adapt to new ways of working.
Earlier this year the firm acquired Magma Products Ltd, a specialist Commissioning and Start-up company. Prior to that they were involved in the acquisition of Apollo Engineering to strengthen their capabilities in the brownfield modifications arena.
Global E&C’s parent company is Global Energy Group and last year they acquired Aiken Group who provide multi-disciplinary engineering and project management services, specialising in modules, accommodation and refrigeration.
Over recent months the Group has taken various steps to safeguard the business and ensure they positioned to come out of this crisis in the right shape.
As part of their efforts, the decision has been made to consolidate Global E&C, Magma and Aiken under a brownfield portfolio structure which will be headed up by Terry Allan in his new role as Executive Director.
Additionally, Global E&C has secured new office Headquarters in Aberdeen’s City Centre where it intends to co-locate its Projects and Engineering teams along with a dedicated Technology Hub.
The new facility forms part of broader restructuring plans to help stabilise the business as a result of the ongoing COVID-19 crisis and depressed commodity prices. The move also links to Global E&C’s growth aspirations and drive towards its digitally led EPC offering.
Along with the new HQ, Global E&C is undertaking a reshuffle of their existing sites. All of the company’s fabrication facilities have been consolidated to the Nord Centre, Aberdeen where the division will be collocated with the Aiken business.
This move significantly enhances the fabrication and modular build services and offers direct access to Aberdeen harbour for the loadout of larger scopes.
Commenting, executive director, Terry Allan said: ‘The context in which we operate is moving faster than any of us have ever experienced. As a business we need to adapt to market changes in order to remain relevant and maintain our progressive market position in the EPC space. There remains a lot of uncertainty in the Oil & Gas industry which now needs to reinvent itself in many respects in order to extend the life of fields in the UKCS. We feel that we are positioned very well to support the UK energy market as it transitions over the coming years where we must strike the balance between driving down cost for existing offshore assets, accelerating our energy transition objectives and utilising value added technologies across all areas.”
Russia’s Gazprom signed a Memorandum of Intent with the Mongolian Government to look at the feasibility of building and operating a gas pipeline across Mongolia.
A working meeting between Alexey Miller, Chairman of the Gazprom Management Committee, and Ukhnaagiin Khurelsukh, Prime Minister of Mongolia, took place via a video call.
The parties discussed the prospects of cooperation on the project for pipeline gas supplies from Russia to China across Mongolia.
In the course of the meeting, Alexey Miller and Yangugiin Sodbaatar, Deputy Prime Minister of Mongolia, signed a Memorandum of Intent to set up a special-purpose company. The company will be established in Mongolia with the purpose of conducting a feasibility study for the construction and operation of a gas trunkline.
In December last year, Gazprom and the Government of Mongolia signed a Memorandum of Understanding to look at the feasibility of pipeline gas supplies from Russia to China across Mongolia.
The throughput of the new export channel from Mongolia to China may reach up to 50 billion cubic meters of gas per year.
KBR has been awarded two contracts by Ningxia Baofeng Energy Group Co. (Baofeng Energy) for its 500KTA coal to olefins project & 500KTA C2-C5 comprehensive utilisation project to be built in Ningdong Town, Lingwu City, Ningxia, China.
Under the terms of the contracts, KBR will provide process technology licensing and process design packages for this project, which will have an annual production capacity of one million tons of olefins. Once completed, the complex will be the largest single-train methanol to olefins (MTO) plant in the world.
KBR will use a combination of its SCORE steam cracking and MTO recovery technologies to achieve Baofeng Energy's project objectives of highest yields and lowest capital investment.
The SCORE steam cracking unit will convert the ethane and propane feedstock into ethylene and propylene, which are later separated and further purified in the MTO recovery section to ensure the quality needed to produce polymer grade ethylene and propylene.
"We are proud that Baofeng Energy has selected KBR for this breakthrough world-scale MTO complex," said Doug Kelly, KBR president, Technology Solutions. "This award is a reaffirmation of our continued commitment to helping our clients maintain their competitive edge through technological advancements and delivering the best return on their investments."
Turkey said it has made a large gas find at Tuna-1 in the Black Sea and found 320 billion cubic metre of gas that could transform the country into a net exporter by 2023.
Thomas Purdie, an analyst on Wood Mackenzie’s upstream research team, said: “Even if the official 320 billion cubic metre figure given by President Tayyip Erdogan when he announced the discovery is treated as an estimate of gas in place, this is Turkey’s biggest-ever find – by a wide margin – and one of the largest global discoveries of 2020.
He added: “However, no matter the political and economic importance, reaping the supply rewards will be complex and a 2023 date for bringing the discovery – renamed Sakarya - looks ambitious.
“First and foremost, the discovery will need to be appraised by more wells – to improve understanding of the geology and confirm resource estimates.
“It’s early days, but any future development would cost billions of dollars. Deepwater projects are complex in any environment, but the Black Sea poses additional logistical challenges that must be managed. This is one of the factors that has stalled Romania’s Neptun Deep megaproject, located just 100 kilometres north of the Tuna well.”
Purdie said TPAO would benefit from bringing an international partner into the project, adding: “There could be attractions despite the market outlook – highly competitive tax terms in a basin that international oil companies know increasingly well over recent years. Majors operating across the border in Romania and Bulgaria have had mixed recent success, but will take note of this momentous news.”
Murray Douglas, director, Europe gas, said: “The Turkish gas market is large, with 2019 demand of almost 45 billion cubic metres.
“Gas demand has fallen year-on-year since 2017. Much of that is down to the weak Turkish economy and increased competition from coal-fired and renewable generation.
“However, despite coronavirus, Turkish gas demand has only fallen 3%, year-to-date, versus last year. That is a less severe fall than many other European markets.”
Douglas added: “In the 2020s, this discovery could have far-reaching implications for future gas imports and upcoming negotiations with suppliers – with Gazprom, Azerbaijan and Iran.”
AVEVA has announced that it will buy OSIsoft for US$5 billion which will help accelerate digital transformation of the industrial world.
AVEVA and OSIsoft will combine their complementary product offerings, bringing together industrial software and data management to help customers in industrial and essential organisations accelerate their digital transformational strategies as efficiency, flexibility, sustainability and resilience become increasingly urgent requirements for customers.
OSIsoft’s data management software will complement AVEVA’s comprehensive end-to-end engineering, operations, and performance offerings. Integrating OSIsoft’s PI System into AVEVA’s comprehensive software portfolio will create an integrated data foundation that can drive big data, Cloud and AI-driven insights to create meaningful business outcomes for customers. This combination enables AVEVA to grow and diversify the industries it serves as well as continue to expand its footprint in existing and new markets and geographies.
Commenting on the agreement, Craig Hayman, CEO of AVEVA, said: “Combining AVEVA and OSIsoft is yet another significant milestone in our journey to achieving the ambitious growth goals that we have set. This will not only help us serve existing customers better but also open the flood gates to new opportunities which will accelerate the delivery of our digitization vision. Data has been enabling organizations to more effectively determine the cause of problems by allowing them to visualize what is happening in different locations, departments and systems. This agreement will enable our customers to improve business processes as well as eliminate inefficiencies. We are extremely proud to be moving into the next chapter with an even stronger solutions portfolio as well as an ever-increasing and robust customer base which continues to make us leaders in our sector.”
Together, AVEVA and OSIsoft can provide full-stack solutions that span edge, plant, and enterprise deployment models, strengthening AVEVA’s position as a global leader in industrial software. With a combined 93 years of operating expertise and experience, they share a history of meeting the rapidly changing and evolving needs of their industrial customers, built on foundations of customer centricity and world-class talent.
The complementary product offerings of AVEVA and OSIsoft will allow the combined company to continue to generate significant value for its stakeholders by creating new opportunities for innovation using new and emerging technologies. The two product suites are open and interoperable, and many customers leverage both solution sets today. As a combined entity, AVEVA and OSIsoft can further deliver on their sustainability goals, driving significant benefits and value for their customers.
OSIsoft founder and CEO Dr. J. Patrick Kennedy added: “Joining forces with AVEVA enhances and extends our ability to deliver on our key commitments to our customers, partners and employees. Together we will be better able to service the largest digital transformation projects in history, including across industry 4.0+ and IIoT. AVEVA’s interest in OSIsoft is a testament to our talented team, and the extraordinary value of the PI System as the real-time streaming data infrastructure that powers the industrial world. Today’s announcement is the culmination of a thoughtful search for a respected organization that would mesh with our own strong mission- and customer-driven culture.”
Air BP, the international aviation fuel products and services supplier and Neste, the world’s largest producer of renewable diesel and sustainable aviation fuels (SAF), have signed an agreement to offer an increased volume of sustainable aviation fuel to airport customers in 2020 and 2021.
The volume is five times larger than that supplied by the businesses in 2019. Air BP will make the Neste-produced SAF available at selected airports in Europe, with deliveries to airports including Stockholm (ARN) and Oslo (OSL) expected to begin in the coming weeks.
The increased supply of SAF comes in response to rising demand from existing and new airline customers, as well as from Norway, where there is a mandate requiring 0.5 per cent of all jet fuel sold to be SAF.
Neste’s SAF is produced from 100 per cent renewable waste and residue raw materials. In its neat form and over the lifecycle, it can reduce up to 80 per cent of greenhouse gas emissions compared to conventional jet fuel. SAF undergoes the same quality tests as regular fossil jet fuel and can be blended at up to 50 per cent to fuel aircraft. Currently, SAF offers the only viable drop-in alternative to fossil liquid fuels for powering commercial aircraft.
“BP’s ambition is to be a net zero company by 2050 or sooner and to help the world get to net zero. Air bp aims to support our customers and the wider aviation industry on their path to meet their low carbon goals. We believe sustainable aviation fuel will play an important role as the industry recovers from the impact of the COVID-19 pandemic. Through our successful ongoing collaboration with Neste, we are pleased to be able to offer our customers a substantially increased volume of SAF as they work towards reducing their emissions”, says Martin Thomsen, Air BP’s chief executive officer.
“The COVID-19 pandemic and its economic implications have not changed our ambition. We remain fully committed to combating climate change by providing tangible, immediately available solutions for reducing the greenhouse gas emissions of flying in cooperation with our partners. The use of sustainable aviation fuel will play a significant role in the industry’s ongoing efforts in making air transportation fit for the climate and environmental challenges it is facing. We are looking forward to continuing our close collaboration with Air BP and jointly contributing to a more sustainable aviation”, says Thorsten Lange, executive vice president, Renewable Aviation at Neste.
Neste’s sustainable aviation fuel annual capacity is currently 100,000 tons. With their Singapore refinery expansion on the way, and with possible additional investment into their Rotterdam refinery, Neste will have the capacity to produce some 1.5 million tons of SAF annually by 2023.
Air BP has supplied SAF since 2010 and, to date, has supplied more than 20 customers and 16 airports globally, including Norway’s Oslo Airport where it was the first to supply SAF produced by Neste through the existing airport fuelling infrastructure, in collaboration with other industry stakeholders.
Total and its partners have taken the investment decision for the third phase of the Mero project (Libra block), located deep offshore, 180 kilometers off the coast of Rio de Janeiro, in the prolific pre-salt area of the Santos Basin.
The Mero 3 FPSO1 will have a liquid treatment capacity of 180,000 barrels per day and is expected to start up by 2024. It follows investment decisions for Mero 1 (startup expected in 2021) and Mero 2 (startup expected in 2023) FPSOs, both of which have a liquid processing capacity of 180,000 barrels per day.
“The decision to launch Mero 3 marks a new milestone in the large-scale development of the vast oil resources of the Mero field – estimated at 3 to 4 billion barrels. It is in line with Total's growth strategy in Brazil’s deep-offshore, based on giant projects enabling production at competitive cost, resilient in the face of oil price volatility,” said Arnaud Breuillac, president Exploration & Production at Total. “The Mero project will contribute to the Group’s production from 2020 onwards, and we are targeting a production of 150,000 barrels per day in Brazil by 2025.”
The Mero field has been in pre-production since 2017 with the 50,000-barrel-per-day Pioneiro de Libra FPSO.
The Libra Consortium is operated by Petrobras (40 per cent) as part of an international partnership including Total (20 per cent), Shell Brasil (20 per cent), CNOOC Limited (10 per cent) and CNPC (10 per cent). Pré-Sal Petróleo (PPSA) manages the Libra Production Sharing Contract.
Global energy consultancy Xodus Group has launched a three-year collaborative research project on the costs around floating offshore wind.
The study, led by Xodus through the IDCORE programme, is a collaborative partnership between the Universities of Edinburgh, Strathclyde and Exeter as well as the Scottish Association for Marine Science (SAMS). To enable the best industry outcomes, Xodus is issuing an open call to developers and technology suppliers to engage with the study from the outset.
The project will be key to ensuring floating wind can be a serious contender in the energy mix going forward and will result in a tool designed to assist in key decision making for floating offshore wind projects. It will also create guidance to assist with project finance decision making and to reduce uncertainties in floating offshore wind energy yield assessments.
Titled ‘Improving the Bankability of Floating Offshore Wind Projects’, the study will tackle the challenges and risks that project developers have in acquiring finance for floating wind projects and develop a methodology to use floating LIDAR data for bankable energy yield assessments.
The study will explore the impacts of floating structures on modelling wind resource and incorporating the impact of met ocean conditions on site considerations.
Scott Hamilton, Renewables Division manager at Xodus said: “We have a strong track record of engaging with leading academic research and are proud to be leading this collaborative project in floating offshore wind. It’s important for us to be investing in future skills that the industry needs.
“We are openly inviting developers to engage with us on this project from the outset, and we expect the outcomes to provide much needed innovative research in this area and deliver benefits to the wider wind industry.”
The IDCORE programme addresses future challenges to develop leading technologies and train world-class scientists and engineers essential for the UK to sustain its global status in the ORE sector.
Petrofac, in a joint venture (JV) with the state oil company of the Republic of Azerbaijan (SOCAR), has secured a contract to provide BP Azerbaijan with international payroll and personnel support services including training services.
The five-year contract, worth around US$100 million to the JV, will support the provision of international payroll and personnel support services, including support of Company personnel attending training courses inside and outside of Azerbaijan.
SOCAR vice-president for HR, IT and regulations Khalik Mammadov said: “The service sector has contributed significantly to SOCAR’s income in recent years, with our joint venture with Petrofac becoming a major part. We are pleased to lift our partnership with BP to a new level and look forward to many decades of fruitful cooperation. Upskilling and reskilling of personnel is crucial for major companies in the age of Industry 4.0. That becomes even more important in view of the challenges brought by the current pandemic and recent associated market conditions. I strongly believe that the demand for professional training services among the leading oil and gas companies will continue to grow.”
Patty Eid, Global Head of Petrofac’s Training Services business, commented: “BP are an important longstanding customer and we look forward to supporting them with international payroll and personnel support services including training services inside and outside of Azerbaijan. Petrofac’s Training Services business has been providing skills development opportunities across the country’s oil, gas and petrochemical industries since 2004, so this award further underpins our continued expansion in the region with key partner SOCAR.”
Chevron and Novvi announced the first production of 100 per cent renewable base oil from Novvi’s Deer Park, Houston Facility.
“As part of our aim to find more reliable, affordable and ever-cleaner solutions that scale, Chevron remains committed to our investment in and technology development with Novvi,” said Colleen Cervantes, Chevron Lubricants president. “This milestone reflects the focus in our partnership despite the recent pandemic-related downturn, and we are excited about the future.”
Chevron is an equity investor in Novvi, a California-based company that engages in the development, production, marketing, and distribution of high-performance base oils from renewable sources. The agreement was announced in 2016.
This development is the latest in a series of Chevron announcements signaling its commitment to the energy transition and climate change focused on three areas: 1) lowering carbon intensity cost efficiently, 2) increasing renewables in support of its business, and 3) investing in the future targeting breakthrough technologies.
“Novvi is focused on delivering renewable solutions—essential chemicals and products for the industrial fluids and lubricants markets—without trade-offs in performance, price, or availability,” said Jeff Brown, Novvi president and CEO.
The Chevron-Novvi partnership leverages the complementary technologies of Chevron’s long-standing expertise in hydroprocessing, particularly ISODEWAXING, with Novvi’s innovative use of renewable feedstocks to produce and market high-performance, synthetic and renewable premium base oils.
Novvi has developed renewable products through its technology platform that are also applicable in plastics, rubber, personal care, wax, and electric vehicle fluids. The invention and scale of this technology is designed to provide more choice to manufacturers aiming to improve performance and reduce the carbon intensity of their products.
The African Export-Import Bank (Afreximbank) is supporting the advancement of Mozambique’s energy industry and economy by committing up to US$400 million in guarantees and direct lending to the Area 1 LNG Project.
The total Project is estimated to cost about US$24 billion and is set to be the largest private foreign direct investments in Africa, and one of the largest LNG projects in the world. It will play a key role in Mozambique’s economic growth and support the wider region.
The $400 million financing will be used to partially finance the project development activities required to extract natural gas offshore, its transfer to onshore processing facilities and then its conversion to LNG for export to various markets around the world.
The Mozambique Area 1 LNG project is an integrated LNG development that will initially comprise two LNG liquefaction trains – each capable of processing 6.44 million metric tonnes a year. The initial development is expected to produce more than sixteen trillion cubic feet of gas and ninety-three million barrels of condensate over the 30-year development and production period.
A key focus is for the project to be developed in an environmentally and socially sustainable manner and that it operates responsibly, protecting the environment, as well as the health and safety of the public, employees and contractors. Investment into the region will create jobs, increase the standard of living and is expected to drive long-term sustainable economic growth for the country and the region.
The $400 million commitment to the project is in line with Afreximbank’s strategy of promoting intra-African trade as well as industrialisation and export development. The guarantee is done jointly with Export Credit Insurance Corporation of South Africa SOC Limited (ECIC) which has enabled significant African contribution to the overall financing of the Project. This joint collaboration is offered under the South Africa-Africa Trade and Investment Promotion Programme (SATIPP), launched in 2018, to promote and expand trade and investments between South Africa and the rest of Africa.
Prof. Benedict Oramah, President of Afreximbank, said: “We are confident the Mozambique LNG project will create opportunities for the people of the country and drive sustainable economic growth. We believe that the success of projects such as this will create a precedent through which other development projects in Africa can secure funding and gain international traction. We are delighted to be one of the key stakeholders involved in this project which will accelerate the rate of growth of intra-African trade.”
Following the regulatory approvals and the agreement of partners, Total closed the sale of UK North Sea non-core assets to NEO Energy.
“As announced on May 20, we have worked closely with HitecVision and its portfolio company NEO Energy to conclude this sale. This sale of assets contributes to the action plan currently being implemented to address the economic crisis by focusing on cash delivery and demonstrates our ability to relentlessly lower the breakeven of our portfolio,” declared Jean- Pierre Sbraire, chief financial officer of Total.
The detailed transition plan prepared with NEO Energy will ensure a smooth transfer of operations.
Eni and ASSTRA, the national association of local public transport companies in Italy, have signed a collaboration agreement to implement a series of initiatives and trials to decarbonise transport and reduce the levels of particulates released into the air, using a holistic and technologically neutral approach to identify the appropriate solution for each area of use.
The agreement provides for joint studies to share expertise, mutual participation in thematic working groups and the promotion of a joint position paper highlighting the different existing energy, technological and organisational opportunities.
These opportunities include those deriving from the integration of public transport and forms of sharing mobility, the use of biolubricants and biofuels in public transport and the application of the Life Cycle Assessment (LCA) and "Well to Wheel" approach in assessing the impact the various mobility solutions have on emissions.
Hydrogen mobility is also included in the agreement. Eni and Asstra will assess the possibility to begin experiments involving the use of hydrogen as an alternative fuel.
The agreement aims to promote training initiatives for member companies and public transport users to help create and disseminate a culture of circularity and greater environmental and social awareness of alternative mobility solutions.
UK's BP has reported big losses of US$16.8 billion for the second quarter as it halves its dividend and lays out a new 10 year energy strategy to deliver its net-zero ambition.
The reported loss of $16.8 billion compares with a profit of $1.8 billion for the same period in 2019. BP had second-quarter underlying losses of $6.7 billion, with the main hit coming from $17.4 billion of impairments and exploration write-offs.
“These headline results have been driven by another very challenging quarter, but also by the deliberate steps we have taken as we continue to reimagine energy and reinvent bp. In particular, our reset of long-term price assumptions and the related impairment and exploration write-off charges had a major impact. Beneath these, however, our performance remained resilient, with good cashflow and – most importantly – safe and reliable operations,” Bernard Looney chief executive officer said.
BP also announced a new dividend structure. The dividend has been reset to 5.25 cents per share per quarter (compared to 10.5 cents per share for the previous quarter) and intends to remain fixed at this level. It is the first time BP has cut its dividend since the Gulf of Mexico disaster ten years ago.
BP also introduced a new strategy alongside its results that will reshape its business as it pivots from being an international oil company focused on producing resources to an integrated energy company focused on delivering solutions for customers.
Looney explained: “BP has been an international oil company for over a century - defined by two core commodities produced by two core businesses. Now we are pivoting to become an integrated energy company - from IOC to IEC. From a company driven by the production of resources to one that that’s focused on delivering energy solutions for customers.
Within 10 years, BP said it aims to have increased its annual low carbon investment 10-fold to around $5 billion a year, building out an integrated portfolio of low carbon technologies, including renewables, bioenergy and early positions in hydrogen and CCUS. By 2030, BP aims to have developed around 50GW of net renewable generating capacity – a 20-fold increase from 2019 – and to have doubled its consumer interactions to 20 million a day.
Over the same period, BP’s oil and gas production is expected to reduce by at least one million barrels of oil equivalent a day, or 40 per cent, from 2019 levels. BP will also make no exploration in new countries.
By 2030, BP aims for emissions from its operations and those associated with the carbon in its upstream oil and gas production to be lower by 30-35 per cent and 35-40 per cent respectively.
“Energy markets are fundamentally changing, shifting towards low carbon, driven by societal expectations, technology and changes in consumer preferences. And in these transforming markets, BP can compete and create value, based on our skills, experience and relationships. We are confident that the decisions we have taken and the strategy we are setting out today are right for BP, for our shareholders, and for wider society.” Helge Lund, chairman.
Speaking after BP's Q2 earnings announcement, Luke Parker, Wood Mackenzie Vice President - Corporate Analysis, said:
"Today’s strategy update marked a big step forward, filling in many of the blanks, including detailed guidance to 2030. It leaves stakeholders with a much clearer of idea of where BP is headed over the next decade, how it will to get there and what that means for the value proposition.
"We said back in February that no company of BP’s stature had gone as far, or committed so unequivocally, to transforming itself in the face of the energy transition. The guidance that BP laid out today brings that transformation to life – makes it real. It constitutes the clearest and most detailed roadmap to Big Energy that any of the Majors have provided to this point.
"BP's oil and gas business will shrink dramatically, while the low carbon business will grow strongly.
“But if ever there was a moment to reset, this was it. Several factors have converged to make it possible: coronavirus and everything that comes with it; a strategic pivot to net-zero on the horizon; Shell’s dividend reset; a new leadership with credit in the bank. Our view is that BP has taken the prudent course of action."
Neptune Energy and its partners announced the commercial discovery of oil at the Dugong well in the Norwegian sector of the North Sea, the largest discovery in Norway so far this year.
Dugong is located 158 kilometres west of Florø, Norway, at a water depth of 330 metres, and is close to existing production facilities. The Dugong prospect consists of two reservoirs that lies at a depth between 3,250 – 3,500 metres.
The volumes are estimated to be in the range of 6.3 – 19.0 million standard cubic meters (MSm3) of recoverable oil equivalent, or 40 – 120 million barrels of oil equivalent (boe), Neptune Energy said in a statement.
Neptune Energy’s managing director in Norway, Odin Estensen, said: “This is a significant discovery and strategically important for Neptune Energy in this region. Dugong may also open up additional opportunities in the surrounding licences, with the potential for a new core area for Neptune in Norway.”
In addition, the Dugong discovery has significantly de-risked another prospect in the licence estimated by Neptune at 5.2 million standard cubic meters (MSm3) of recoverable oil equivalent, or 33 million boe. This brings Neptune’s estimate of the total resource potential in PL882 to as much as 153 million boe.
Neptune Energy’s director of Exploration & Development in Norway, Steinar Meland, said: “The discovery gives new and valuable understanding of the subsurface in this part of the Tampen area.
“We are very pleased to see that our exploration model developed together with our partners has proved to be successful. We will now initiate studies, as well as consider development options for the discovery.”
The discovery well 34/4-15 S and the down-dip sidetrack 34/4-15 A proved oil in the Viking and Brent Groups of the Dugong prospect. These are the first exploration wells in production license 882. The license was awarded in 2017 as result of the Norwegian licensing round Awards in Predefined Areas (APA).
Dugong partners: Neptune Energy (operator and 40 per cent), Concedo (20 per cent), Petrolia NOCO (20 per cent), and Idemitsu Petroleum Norge (20 per cent).
Aker Solutions has secured a five-year contract extension from ExxonMobil for the provision of engineering, procurement and construction (EPC) services for the Hebron platform, offshore Newfoundland, Canada.
The contract is an extension for a 5-year period, starting in the summer of 2020. Aker Solutions has provided EPC services to Hebron since 2015. The work will be led from Aker Solutions’ premises in St. John’s, Newfoundland and Labrador.
Aker Solutions estimates the contract value to be NOK 1.4 billion, which will be booked as order intake in the third quarter of 2020.
“We are delighted to be extending our strong relationship with ExxonMobil in Canada, and to further strengthen the international footprint of our brownfield services business,” says Linda Aase, executive vice president, brownfield projects, at Aker Solutions.
Weatherford International announced it successfully and remotely used a restricted crew to install a 16-inch liner hanger on an offshore platform in Sakhalin Island, Russia during the COVID-19 lockdown.
Remote training and monitoring procedures enabled the successful installation of the liner hanger system, cementing products and tubular running services.
The operator objectives were clear: First, install and cement a 16-inch liner and hanger at an offshore platform that was locked down as a precaution to protect against COVID-19 viral exposure. Second, provide remote guidance and technical support to ensure a trouble-free liner installation. The lockdown restricted the number of personnel aboard the platform to reduce potential contamination risks.
“The Weatherford liner team developed remote training and monitoring procedures to enable successful installation and testing of a 16-inch liner using a restricted crew that reported zero equipment malfunctions,” said Fayaz Kamalov, vice president, Russia, Weatherford. “Weatherford met all service quality and HSE standards in absolute accordance with the operator’s expectations.”
The Weatherford team provided remote guidance to ensure a trouble-free outcome for each step, including equipment rig-up, liner running, hanger installation, cementing, packer setting, pressure testing, and rig-down. The liner team prepared schematics and training videos on equipment preparation and installation for the operator to share with platform workers. As their next step, the liner team set up an office at the Weatherford Sakhalin base to provide remote, 24-hour support for the installation. They also monitored and assisted the equipment preparation and loadout before transporting it to the platform.
To assure the job went smoothly, the liner team held online conferences before each major step, from rig-up to installation, cementing and rig-down. The liner team also reviewed photos and remotely monitored equipment-preparation videos sent by the operator representative to confirm that procedures were conducted properly. From their shore base, the liner team guided the platform crew through each process to successfully set, cement and pressure-test the liner.