Allseas has reported that Brent Charlie topsides have been successfully delivered to Able UK’s Seaton Port in Hartlepool, UK.
Weighing more than 31,000 t, Brent Charlie is the largest single offshore topsides to be lifted, transported and delivered to shore, according to Allseas. It was initially removed in a single lift by the Pioneering Spirit, Allseas’ heavy lift vessel that is capable of lifting entire topsides of up to 48,000 t and 20,000 t jackets.
After being carried on the vessel to near-location, the topsides was transferred to the custom barge, Iron Lady, for the short tow to the Tees Estuary and onwards to the Seaton Port disposal facility.
Barge and topsides were grounded onto the grounding bed in the wet dock for the load-in. All safety checks complete, the former production platform was skidded onto Quay 6, designed specifically to distribute the weight of the heaviest topsides facilities.
Now delivered, the massive topsides will be decommissioned with as much recycled or re-used as possible. Able UK has achieved over 97% recycling/re-use rates on previously decommissioned Brent topsides Delta (24,000 tonnes), Bravo (25,000 tonnes), and Alpha (17,000 tonnes), and aims to match or exceed this figure for Charlie using its well-established supply chain.
Bhagwan Marine Limited, an Australian marine services company, has announced that it will commence trading on the Australia Securities Exchange (ASX) as it seeks to pursue a number of growth opportunities.
The decision comes following a successful initial public offering of fully paid ordinary shares. The offer comprised the issue new shares by the company to raise $80mn before costs and received strong institutional support.
This will allow the company to strengthen its balance sheet and enable it to pursue a number of prospective opportunities around the oil and gas, offshore wind, infrastructure, defence and decommissioning sectors.
Bhagwan Chairman, Anthony Wooles, commented, “Bhagwan is now entering an exciting new growth phase with the emergence of the oil and gas decommissioning sector, and the future development of the offshore wind energy sector. I am excited about the opportunities and potential for the company to expand into new industry segments. Bhagwan’s strong operational and safety performance, along with its passionate focus on clients, personnel, culture, and service delivery, will continue to benefit the company as we pursue sustainable earnings growth.”
This step is recognised as the next chapter for a company which was founded in 2000 with a single vessel. Now, the fleet has expanded from increasing demand for its services to a diversified fleet of around 100 inshore and offshore vessels. These will certainly be put to use in the next phase of the company’s journey as it looks to take advantage of the emerging markets in Australia.
Geothermal services provider DMT GmbH & Co. KG will be exploring geothermal potential in Münster for Stadtwerke Münster GmbH who commissioned the project as part of the 2030 decarbonisation strategy
The project will involve a large-scale 3D seismic measurement campaign before winter 2024/25, surveying the deep underground between 1,400 and 7,000 meters, covering the entire city.
"25% of the heat demand in Germany could already be covered in the long term, sustainably and CO2-neutrally using deep geothermal energy. The first steps to accelerate the heat transition with the help of deep geothermal energy have been taken. Now it is important to consistently use and roll out instruments such as exploration loans or insurance, national and international funding and accelerated approval procedures. This means that projects like the one in Münster can soon be implemented throughout Germany," said Maik Tiedemann, Chairman of the Management Board / CEO of DMT, and CEO of the TÜV NORD GROUP Business Unit Energy & Resources.
The campaign will see five vibrator fleets working in parallel, consisting of up to 18 vibro trucks and a measuring crew of around 80. Data collected from the campaign will influence further planning and implementation of the heat transition using deep geothermal energy in Münster and the associated decarbonisation.
"The upcoming measurements in the deep underground around Münster will provide valuable information to specify the agenda for the use of deep geothermal energy in the Münsterland and to define a roadmap for this project. With our recent acquisition of high-quality and state-of-the-art measuring instruments, we are also well prepared for the expected increase in orders," said Thorsten Müller, Head of Business Entity Exploration Seismic at DMT, who leads operational teams.
Electrocentrale București (ELCEN), one of Romania’s leading producers of thermal and electric energy, has signed a MoU with Sage Geosystems for the carrying out of a feasibility study for the implementation of geothermal technologies in the Bucharest district heating system.
The benefits of this collaboration are aimed at ensuring sustainability, innovation and efficient economic solutions for the future of centralised heating in Bucharest in an approach that is consistent with the national and European energy transition objectives.
Through the MoU, ELCEN will facilitate access to the relevant data and necessary infrastructure in order to carry out the study, and will contribute its technical expertise and specific operational knowledge to the centralised heating system within Bucharest. Sage Geosystems will perform the technical and geological analysis and feasibility study on the geothermal utilisation solution.
The aim of the partnership is to explore how geothermal energy can be implemented within the city the replace a fossil fuel-based thermal plant with a clean alternative. The first project is expected to generate up to 70MW of thermal power for a district in Bucharest, and upon its a success, will be expanded to other Romanian projects and cities.
General Director of ELCEN, Claudiu Crețu, stated, “We signed this Memorandum of Understanding to see how we can use the geothermal potential in the coming years for the heating of Bucharest as efficiently and sustainably as possible in a hybrid approach."
Cindy Taff, CEO and Co-Founder of Sage Geosystems, commented, “Sage is thrilled to be supporting Romania’s transition to clean energy and to introduce geothermal energy applications to its capital city.”
Offshore Network has released a new report on the Offshore Well Intervention Market in the Gulf of Mexico.
The new research comes ahead of the OWI GOM 2024 Conference arriving in Houston from 21-22 November. This is apt timing for it will closely follow after the US election – a significant event that will greatly affect the future of the offshore oil and gas industry in the region. The return of Republican candidate, Donald Trump, to the White House will likely herald a wave of drilling and a slackening of regulations rung tighter under the tenure of President Biden. However, should the Democrat nominee win, then the focus will likely remain on restricting further assets being created and greater emphasis on operators to fulfil the ever-growing decommissioning scope of work.
Regardless of this outcome, according to most market commentators, global demand for oil and gas is set to remain at least for the short-term, and likely for longer. With drilling becoming an increasingly distasteful option in much of the public eye, production enhancement to maintain rates and extend asset life is becoming increasingly attractive – if the recovery factor of mature assets is boosted by just 1%, then 2-3 years of additional consumption could be satisfied. These dynamics are creating a favourable outlook for the well intervention market in GOM, and service providers are looking to take advantage by bringing new technology into play of ever-increasing sophistication.
Perenco UK has completed a campaign of velocity string installations on five wells at the West Sole Charlie platform in the Southern North Sea (SNS), situated 70 km east of Perenco’s Dimlington terminal on the Yorkshire Coast.
The campaign was conducted by the Petrodec HAEVA rig and has delivered sustained production gains of around +5 MMscf/d, in line with expectations.
In a technical and commercial feat, the company completed ahead of schedule. Each of the wells are seeing improved production rates, running with 100% uptime, withouth the need for cycling. Two of these wells were brought online from scratch as they remained shut-in and were not producing.
The net effect is a new production rate for the West Sole field sustained above the 30 MMscf/d level. Recompletion using velocity strings is a proven technology in fields that are no longer producing at their original high gas rates.
In the case of West Sole, the original completion with 5½” tubings were no longer optimal, given the now partially depleted reservoir. Inserting velocity strings of narrower diameter helps to increase the fluid velocities, thereby sustaining production at lower pressures and allowing extension of field life. Perenco had previously deployed this technique to good effect in 2020 at the Hyde field and decided to continue with similar deployment at West Sole Charlie. Other SNS fields, such as Apollo, are also being evaluated for the same.
Perenco UK SNS Managing Director, Jo White, said, “Demand for gas in the UK is set to remain high, so enhancing recovery from domestic gas fields is vital for both energy security and for improving overall emissions intensity. Local natural gas resources have a significantly lower carbon footprint than imported liquified natural gas (LNG), which today accounts for a high proportion of the balance of supply. West Sole was the first offshore natural gas field to be developed in the UK. Since 1967, it has delivered cumulative production of more than 2.2 trillion cubic feet of gas. It remains a significant production hub in the SNS offshore gas network, with potential for future development and tie-in of nearby gas discoveries. Through renewal and application of new technology a sustainable and productive future remains possible for decades to come for the West Sole field.”
Offshore Network has released the Wells Latin America 2024 Outlook that reviews the region's intervention and decommissioning drives, while considering the wave of new technology revolutioninsing the industry.
The push behind these industry innovations come from watchdog organisations such as the Brazilian National Agency of Petroleum, Natural Gas and Biofuels (ANP) or Brazilian Institute of Environment and Renewable Natural Resources (IBAMA), which make sure that exploration and production activities are being carried out in a responsible and sustainable manner.
In Brazil, Petrobras have approximately 500 well interventions planned over the next 10 years, and also a significant decommissioning workload, which it has outlined in its 2024-2028 strategic plan. To achieve these feats, the company is actively researching cost-effective means to go about the task. Petrobras has plans to introduce thermite melting delivery in its operations this year. If all goes well, through tubing thermite P&A (TT P&A) delivery is expected by 2026, and the company is eyeing up the prospect of adopting self-abandonment technology by 2030.
The region's growing well intervention industry is taking inspiration from North Sea, where companies such as BiSN and RockSolid are introducing fresh approaches to well services. BiSN’s wel-lok technology, for example, uses bismuth as permanent seal for P&A operations, while RockSolid uses organic well barriers, eliminating the need for rigs or heavy equipments.
Reflecting on these landmark industry transformations that are currently sweeping through the region, Wells LATAM 2024 conference promises fully-rounded discussions and engaging exchanges.
In an operational update from the SASB gas field well intervention programme, Trillion Energy International has noted the improved flow rates from the South Akcakoca-2 well.
“The fantastic response of South Akcakoca-2 once the water was lift off the perforations indicates that the reservoirs will produce the gas they contain once the water loading is removed. The wells are going to be perforated and monitored during clean up to evaluate the reservoirs response. The next phase of this project is to install the smaller production tubing (2 3/8”) to allow the wells to produce for a few years before water loading occurs again," Arthur Halleran, CEO of Trillion, said.
The South Akcakoca-2 well was perforated over the intervals 2319.5-2323.5 (4.0 m), 2339.6-2341.3 (1.7m) and 2411.1-2412.8 (1.7m) for a total of 6.4 m (all measured depth MD). Well hole pressure (WHP) was 86 psi before perforation, the WHP increased to 1046 psi.
The well flowed continuously from early 9 July, and by 10 July afternoon the flow rate was 0.70 MMcf/d with a WHP of 140 psi. By 15 July, the flow rate was 2.88 MMcf/d with a WHP of 318 psi.
Monitoring of the South Akcakoca-2 well will be continued until it hits a stable point.
The production characteristics indicated that perforating the new zones blew the water out of the well, while also implying that the reservoirs that were water-blocked are cleaning up and producing gas.
Guluc-2 well was perforated over the intervals 3512-3514.5 (2.5 m), 3749.5-3751.3 (1.8 m), 3770.7-3772.4 (1.7m) and 3781.6-3783.3 (1.7m) for a total of 7.7 m (all MD). WHP was 650 psi and increased to 1243 psi before settling to 1098 psi.
Guluc-2 will be flowed to clean the water and perforation debris out and be capable of gas production, however, it will then be shut in while South Akcakoca-2 well gas production stabilises.
The increase in the WHP during perforation indicates gas flowed into the borehole from the new perforated zones.
Updated flow rates have yet to be established for this well due to the ongoing testing of SA-2.
The perforation operation is currently continuing ongoing on West Akcakoca-1 well after which it will perforate the remaining pay in Akcakoca-3.
The North Sea Transition Authority (NSTA) has warned North Sea operators that they must act now on well decommissioning or risk losing the support of the associated supply chain which will begin to look elsewhere in search of work.
Repeated delays to well plugging and abandonment work, competition for rigs from overseas and cost pressures are pushing up the estimated bill for decommissioning on the UK Continental Shelf – information made clear in the latest Decommissioning Cost and Performance Update from the organisation. According to this report, operators expect to spend about UK£24bn on decommissioning between 2023 and 2032, up UK£3bn on the forecast for the same period in last year’s report.
The NSTA has drawn attention to the importance of sharing knowledge, learning lessons and producing robust plans which helped lower the cost of decommissioning by an estimated UK£15bn between 2017 and 2022. However, it stated that further improvements have been difficult to achieve as much of the low-hanging fruit has been picked.
More than half of the overall estimate of UK£40bn (in constant 2021 prices) is to be spent during this 10-year period, which shows near-term actions will set the direction for the sector. Embedding good practice now and striking a balance between supply chain capacity and demand for its services is crucial, the NSTA reports.
Pockets of operators continue to collaborate, perform admirably and deliver savings, but the majority need to improve by doubling down on their planning. Operators spent around UK£2bn on decommissioning last year, which was in line with forecasts, but they completed much less work than originally planned. In regard to P&A, the NSTA stated that operators can keep their costs under control and meet their regulatory obligations by engaging early with the UK’s world-leading supply chain, providing details of their inactive wells and, most importantly, placing contracts to get the work done.
Hundreds of wells will need to be decommissioned every year as more oil and gas fields shut down, the NSTA explained. However, operators only achieved 70% of planned well decommissioning activities last year. Some operators, it continued, are deferring in hope that prices will go down in the coming years. However, failing to award contracts reduces the supply chain’s revenues and ability to invest in capacity and resources. Rig contractors are actively seeking opportunities in other regions where operators offer longer, more secure contracts. If this trend continues, prices will increase, as reflected in market forecasts.
In addition to exploring the use of sanctions, the NSTA is spearheading a project to identify which UKCS wells will be ready for decommissioning between 2026 to 2030 and assess the supply chain capacity required to undertake the work in a timely and cost-effective manner.
“With spending forecast to peak at UK£2.5bn per year in the current decade, decommissioning can ensure that the UK’s world-leading supply chain is equipped to help operators clean up their oil and gas infrastructure over the next 50 years and support the carbon storage sector, which will rely on many of the same resources,” said Pauline Innes, the NSTA’s Supply Chain and Decommissioning Director.
“I am concerned that this huge opportunity to safeguard highly-skilled jobs and support the transition will be wasted if operators fail to tackle their well decommissioning backlogs. The supply chain wants to do this work, but it is not physically tied to the UK. Its skills and resources are in demand in other regions, and we are starting to see companies marketing their rigs elsewhere. Operators need to use the supply chain, now, or risk losing it.”
Exciting times lie ahead for the offshore Health, Safety & Environment (HSE) community in the Gulf of Mexico as Offshore Network’s inaugural HSE GOM 2024 Conference is set to debut in Houston on 8-9 October this year.
The event, which will open its doors in the Hilton Greenway Plaza in Houston, is set to make its mark on the HSE sector with attendees gaining exclusive access to operator best practices and innovative technologies while exploring key strategies to enhance safety performances across the region.
Attendees will also hear from regulators (including the Bureau of Safety and Environmental Enforcement) on standards development, industry-leading strategies for cultivating a prosperous safety culture, and the latest cutting-edge advancements in PPE. More than 20 expert speakers are set to take to the stage to cover topics such as safety culture, process safety, planning and preparation, and technology and innovation.
With 150+ HSE decision makers set to be in attendance, ten technology demonstrations, seven networking events and a series of dedicated sessions, the conference promises to provide an insightful and fruitful experience for all who wish to develop their knowledge about all things HSE.
For more information about HSE GOM 2024, head to the website here to download the full agenda and see the complete list of speakers. For any additional enquiries, please contact Jack Heffernan at
A comprehensive session on plug and abandonment (P&A) regulatory update will be delivered by Rafael Augusto do Couto Albuquerque, Rigs and Wells Coordinator, ANP at the soon to happening Offshore Well Intervention Latin America (OWI LATAM), to be held from 18-19 October 2022, in the city of Rio, Brazil.
In this particular session, the region’s premier well intervention conference will provide attendees with in-depth knowledge on analysing the current offshore well decommissioning situation in Brazil to best position businesses and service providers for upcoming P&A work.
Rafael will also shed light on ways to understand the challenges faced by new operators within the Brazilian market to best prepare for future projects. Attendees are also given in-depth knowledge of new intervention technologies and ways to validate the equipment so that the operators and service providers have the opportunity to optimise their toolbox.
OWI LATAM is poised to be the platform for discussion on the region’s offshore well intervention topics. The event features experts from international and regional companies, alongside regulatory bodies and service providers.
To know more about the full programme, click here: https://www.offsnet.com/latam/conference-brochure
Or reach out to the details below:
Rachael Brand
Project Manager
T: +44 (0) 20 3409 3041
In its latest operations update, British independent upstream oil and gas company, Serica Energy, announced that its investment plans for the Bruce and Keith Light Well Intervention Vessel (LWIV) campaign is on track to take place between March and May 2024.
This follows previous campaigns in 2022 and 2023, which have delivered low-cost incremental production. The intervention is expected to restart production from the Keith field this year following successful preparation work on the Keith subsea facilities carried out in 2023. Additional well interventions from the Bruce platform are scheduled for the second half of 2024.
Besides well work on the Bruce and Keith fields, investments in 2024 include four wells in the Triton area (Bittern B1z sidetrack, Gannet E GE-05, Guillemot North West EC1 and Evelyn EV-02). The start date of the B1z sidetrack is set in March 2024. This well and the subsequent three wells are scheduled to take about three months each, meaning that drilling will continue into 2025. Serica has also exercised an option to keep the rig for a further well following completion of the fourth well in the programme (EV-02).
Serica is maturing plans for two infill wells on the Bruce field too with the aim of drilling in 2026.
Abandonment costs in 2024 are forecast to be about £14 million (pre-tax) net to Serica. These will be incurred mainly on the final decommissioning of the Arthur field, situated in the UK Southern North Sea, which was held by Tailwind Energy.
Reflecting on Serica's investment focus on enabling maximum production like from the Bruce and Triton assets, Mitch Flegg, Chief Executive of the company, said, "Production in 2024 is expected to be higher than in 2023 with guidance between 41,000 boe/d and 48,000 boe/d for the year. This reflects a range of outcomes in a year of significant activity including the speed with which the scheduled drilling and well work deliver incremental production.
"Serica's strategy of investing in its assets continues to be central to our record of consistently achieving high levels of reserves replacement, combined with increased levels of production. We are looking forward, therefore, to the start of the four well Triton area drilling programme in March, with the benefits of added production expected to start coming through in the second half of the year. During 2024 there is also an extensive programme of interventions in both platform and subsea wells on the Bruce and Keith fields. The objectives include re-establishing consistent production from the Keith field.
"In addition, Serica has a healthy portfolio of potential new projects. This includes the possible developments of the Buchan and Belinda fields, which offer the prospect of further replacement of produced reserves and incremental production from 2026 onwards. Our plans for drilling two Bruce infill wells, the first new wells on the field since 2012, are progressing and, during the next eighteen months, we will be participating in the Parkmead operated Skerryvore exploration well situated in the UK Central North Sea. As a UK taxpayer, Serica will benefit from tax relief for its share of the associated development and exploration costs.
"Serica is extremely well placed, therefore, to continue its track record of replacing reserves and increasing production. This platform has been achieved while maintaining a very strong balance sheet, which is both the result and enabler of our strategy to invest and grow organically and through disciplined M&A."
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