Fugro has signed a four-year agreement with Heerema Marine Contractors for survey and positioning support services onboard Heerema’s heavy lift crane vessels.
Fugro’s worldwide reach and technology offers Heerema a solid support base for their global project portfolio, ensuring optimised offshore operations that minimise environmental impact. Fugro will use their innovative vision technologies, such as QuickVision, 3Direct and InclinoCam, combined with remote services and expert teams to optimise Heerema’s offshore installation and decommissioning campaigns across Europe, the Americas, Middle East, and APAC regions.
Fugro’s survey Geo-data and positioning support will assist Heerema in identifying seabed structures and debris while providing centimetre level precision for installation projects. Real-time touchless inspection and monitoring technology offers a much safer, more efficient and sustainable solution to offshore operations.
Remote support will also enable Heerema to monitor their operations in real-time leading to faster and more informed decision-making as their projects progress.
Thijs Prins, Fugro’s Service Line Director Marine Asset Integrity, commented, “Our vision-based technologies and remote services improve staff safety, significantly reduce project complexity, accelerate turnaround times, and allow operations to be conducted in a wider weather window – critical benefits for Heerema as they complete campaigns over the next four years. We’re proud to be delivering innovative solutions that support the responsible installation, maintenance and decommissioning of offshore energy assets.”
D&A GOM 2022
At D&A GOM 2022, the offshore community is set to reunite face-to-face to discuss the challenges and opportunities marking decommissioning and abandonment in the region, listen to sessions delving into current complex situations and network to help each other optimise their strategies. To find out more, download the brochure: www.offsnet.com/da-gom/conference-brochure
Or contact:
Joseph Watson
Project Manager
Offshore Network Ltd.
t: +44 (0) 20 3409 5720
e:
With many oil rigs being decommissioned in the Gulf of Mexico each year, plans of converting rigs for alternatives like offshore multi-trophic aquaculture (finfish, oyster and algae) production and renewable energy, has been on the cards for oilmen and fisheries alike.
US regulations already allow US Gulf of Mexico platforms to be used for other purposes, apart from oil and gas production. Right of Use and Easement (RUE) permits for alternative uses of offshore platforms have been granted in the past and these regulations would also allow for aquaculture and other marine-related activities. Leasing of Gulf of Mexico areas for wind power is expected to begin in late 2022.
Aquaculture is an increasingly important source of nutritious and sustainable seafood for people worldwide. Globally, aquaculture production must double by 2030 to keep pace with demand. This increase in demand for aquaculture products, food security considerations, and job creation has generated the need for skilled workers.
Ivan Puckett, one of the founders of Blue Silo Aquaculture LLC, while speaking to The Fish Site, said, “Our objective is to find as many uses as possible because we will need an income stream to maintain and operate the platforms. There’s enough space on these installations for several projects and the more operations we can have, the better it is.”
Aquaculture is one of the sectors they see as having the most promise for extending the useful shelf life of the platforms.
Puckett believes aquaculture is promising. “The water quality and oxygen levels are good and disease transmission is low. However, travel expenses to and from the platforms are high, the weather can be challenging, with hurricanes not infrequent and living arrangements are more challenging,” he added.
Kent Satterlee, co-founder Blue Silo Aquaculture LLC, informed that the company is planning to initially install a grid of 12 of Innovasea’s SeaStation pens and add another 12 at another platform site.
The SeaStation design includes the ability to be raised above the waterline in calm weather, exposing the netting to naturally defoul in the sunshine and then be submerged to a depth where they will avoid the full impact of any hurricanes or storm events that happen to pass.
“Innovasea also has expertise, materials, equipment and relationships to provide nearly all of the support aspects of the operation. Video monitoring, feeding systems, various marine and atmospheric monitoring devices, design and technical support, IT integration capabilities and much more,” Satterlee noted, while speaking to The Fish Site.
Puckett added that the company is looking into multi-trophic production; with a mixture of finfish, seaweed and oysters, and the University of Miami will be researching species selection.
In this scenario, the mooring grid for the SeaStation pens could also host the downlines for oysters and algae. The platform structure could also serve as host for the downlines.
D&A GOM 2022
At D&A GOM 2022, the offshore community is set to reunite face-to-face to discuss the challenges and opportunities marking decommissioning and abandonment in the region, listen to sessions delving into current complex situations and network to help each other optimise their strategies. To find out more, download the brochure: https://offsnet.com/da-gom/conference-brochure
Or contact:
Joseph Watson
Project Manager
Offshore Network Ltd.
t: +44 (0) 20 3409 5720
e:
W&T Offshore, Inc., an independent oil and natural gas producer, has closed its acquisition of oil and gas producing properties in federal shallow waters in the central region of the Gulf of Mexico from privately-held ANKOR E&P Holdings Corporation and KOA Energy LP.
The assets are located in the Ship Shoal 230, South Marsh Island 27/Vermilion 191, and South Marsh Island 73 fields. After normal and customary post-effective date adjustments, cash consideration of approximately US$30.2mn was paid to the sellers using cash on hand.
The acquisition will add internally-estimated proved reserves of 5.5 million barrels of oil equivalent (Boe) (69% oil) and proved and probable, or 2P, reserves of 7.6 million Boe (75% oil).
It will add more than 50 gross producing wells (average working interest of 80%) across three shallow water fields to the company’s working interests in 41 producing fields. In such a developed field many of these assets will likely be closing in on their twilight years, presenting an opportunity for well intervention service providers to maintain their production rates and extend their life-span.
Tracy W. Krohn, Chairman and Chief Executive Officer, commented, “Now that we’ve closed the transaction, we’ll begin working on realising the synergies we’ve identified and maximising the value of these assets. We will continue to seek other accretive transactions that can further enhance shareholder value.”
The US Department of the Interior has announced that US$1.15bn in funding is available to states from the Bipartisan Infrastructure Law to create jobs cleaning up orphaned oil and gas wells across the country.
This is a key initiative of President Biden’s Bipartisan Infrastructure Law, which allocated a total of US$4.7bn to create a new federal programme to address orphan wells. Millions of Americans across the country live within a mile of an orphaned oil and gas well.
The historic investments to clean up hazardous sites will create good-paying, union jobs, catalyse economic growth and revitalisation, and reduce dangerous methane leaks.
“President Biden’s Bipartisan Infrastructure Law is enabling us to confront the legacy pollution and long-standing environmental injustices that for too long have plagued underrepresented communities,” said Secretary Deb Haaland. “We must act with urgency to address the more than one hundred thousand documented orphaned wells across the country and leave no community behind. This is good for our climate, for the health of our communities, and for American workers.”
Plugging orphaned wells will also help advance the goals of the US Methane Emissions Reduction Action Plan, as well as the Interagency Working Group on Coal and Power Plant Communities and Economic Revitalization, which focuses on spurring economic revitalisation in the hard-hit energy communities.
Nearly every state with documented orphaned wells submitted a Notice of Intent (NOI) showing interest in applying for a formula grant to fund the proper closure and cleanup of orphaned wells and well sites.
The Department released the amount of funding that states are eligible to apply for in Phase One, which includes up to US$25mn in Initial Grant funding and a quarter of the total Formula Grant money available for the 26 states that submitted NOIs. These allocations were determined using the data provided by states from the NOIs and equally considers the following factors required by the Bipartisan Infrastructure Law.
In the coming weeks, the Department will release detailed guidance for states to apply for the Initial Grants. These resources will allow state officials to begin building out their plugging programs, remediating high-priority wells, and collecting additional data regarding the number of orphaned wells in their states.
D&A GOM 2022
At D&A GOM 2022, the offshore community is set to reunite face-to-face to discuss the challenges and opportunities marking decommissioning and abandonment in the region, listen to sessions delving into current complex situations and network to help each other optimise their strategies. To find out more, download the brochure: https://offsnet.com/da-gom/conference-brochure
Or contact:
Joseph Watson
Project Manager
Offshore Network Ltd.
t: +44 (0) 20 3409 5720
e:
As it approaches the five-year anniversary of its first contract with PRT Offshore, Interventek Subsea Engineering has announced that it is shipping out their latest Revolution in-riser safety valve order.
This is for a new 4-1/8” 10,000psi, shear-seal valve, designed for slimline well access with an outer diameter of 15-1/8.
The slimline Revolution valve is the first of its kind and reflects a growing need for technology which is easily scalable to suit the individual challenges of different subsea intervention projects. Like all Interventek’s products, it has undergone extensive testing and meets the latest API 17G industry standards.
The valve will be used for intervention operations in the Gulf of Mexico in more than 2,450 m (8,000 ft) depth of water with an integral intervention arrangement, using a surface BOP for well control with direct vertical well access to the wet xmas trees below. The Interventek slimline valve will be used in conjunction with this arrangement to enable safe and efficient well access.
PRT Offshore already have an impressive fleet of eight additional Interventek Revolution valves in service, which have built up an extensive track record of deployments in the GOM over the last few years.
Intelligent Wellhead Systems (IWS), a leading supplier of digital technologies that improve oil and gas well completion operations, has announced that oil and gas company algorithms to improve completions may now be combined with hydraulic fracturing, wireline, and pressure control job data.
By doing this, customised workflows, threshold alerts, and other analytical applications can be created.
The company’s inVision Technology Platform features a powerful data acquisition and control system, iHub, which is a proven digital technology infrastructure at the wellsite for hydraulic fracturing and wireline operations.
The latest innovation for the platform is the ability to leverage the iHub infrastructure provided by IWS to implement operator-driven analytics on the Edge or in the Cloud. The iHub delivers field-proven data acquisition, storage, bi-directional sync, Edge computing power, and an open infrastructure to enable operators to deploy and implement their own proprietary algorithms or digital workflows on the Edge or in the Cloud.
Bob Duncan, Vice-president of innovation at IWS commented, “There is growing demand from E&P data science teams and completion engineers to implement their software developments on the Edge or in the Cloud. We now have a proven solution of equipment, infrastructure, and hands on the ground to make these implementations possible in a cost-effective manner.”
The inVision Technology Platform integrates engineered safety controls, automated digital standard operating procedure compliance, and Digital Handshake processes to improve the safety and efficiency of hydraulic fracturing valve activation and wireline operations.
On the second day of the Offshore Well Intervention Gulf of Mexico 2021 conference, attention turned to technology and operational excellence and plug and abandonment, before attendees were exposed to a number of in-depth case studies.
As chairman for the second day of the conference, Nathan Wolford, Project Manager at C-Innovation, opened the proceedings by noting that in this modern world it is easy to take energy for granted. “Covid-19 saw a collapse in demand for energy products, but it got better and in 2021 we are rebounding in our energy consumption and forecasts expect that we will meet or exceed the 2019 levels (highest historical levels to date). By 2040 the forecast the energy demand will increase by 30%.
“83% of energy worldwide is derived from fossil fuels and oil is the biggest of this. As oil producers and service companies, the good news is oil and gas is the dominant worldwide energy source and will continue to be for the foreseeable future. Demand will increase by 30% over next three years, so in some ways we have an obligation to create more production and more energy.
“So we going to have to find more efficient ways to increase existing production through production enhancement mechanisms, and find safe and efficient ways to P&A ageing wells and fields and continue to develop technologies to gain efficiencies on these.”
Over the course of the day, this speakers and attendees demonstrated that they clearly had an intention to do so.
For example, one notable highlight was Zach Bruton’s presentation on the solutions that Baker Hughes has in their toolbox for use in the GOM. The Growth Lead for North America Subsea at Baker Hughes outlined the agnostic and modular tooling design programme that they have developed, introducing the Tree Retrieval Tool and the Tubing Hanger Retrieval Tool before discussing passive well monitoring technology and its possible applications in the region. The session, titled ‘Optimising Asset Retirement Through Agnostic Technologies’ was concluded with a case study from the UK and received a good reception from the audience - interest was demonstrated by the many questions that were directed towards Bruton.
Following this session with another equally engaging demonstration by Christopher Thompson, VP of Business Development at United Subsea Specialists. This young company is committed to delivering equipment to reduce critical path time, cost of operations and risk for operators. Thompson presented several innovative solutions his company has brought to the market, such as their 350t-750t Wire Line Frames, which is enabling them to achieve this commitment.
The plug and abandonment section of the day was kicked off with a panel discussion featuring representatives from Chevron, Schlumberger and Welltec. The experts explored the different types of P&A being executed within the GOM before focusing on the value that can be achieved from performing P&A from a dedicated well intervention vessel as opposed to a rig.
The last point of call was turning to case studies which, as the final section of the conference, were last but certainly not least. Highlights here included a presentation from Bruce Trader, President of MADCON Corporation, who reviewed the development and design of the Structural Composite Retrofit (SCR) Process which restores structural integrity and provides long term corrosion protection to severely corroded or damaged conductors and well casings. Trader presented a number of case studies on the SCR Process and noted that, to date, it has been used to restore the original design capacity and provide long term corrosion protection to hundreds of wells.
The final session of the conference was an engaging presentation from Welltec and Wellgrab AS on replacing conventional heavy fishing methods with light controllable intelligent tools. Garry Andrews, Senior Business Development Manager at Welltec described the solutions that Welltec provides for fishing operations, such as the Well Stoker and the Welltec’s Release Device (WRD), touched on why E-line is preferable over the convention heavy means, outlined some related case studies and finally discussed the Wellgrab AS and Welltec collaboration. Geir Magne Mo Johnsen, Founder and COO of Wellgrab AS followed this by demonstrated the capabilities of its digital well intervention robot which can be converted to fish anything inside or outside a well. The versatility and adaptability of this tool means that this is the only tool Wellgrab AS has in its tool suite.
Each session was sandwiched by networking drinks which allowed attendees, for one of the first times in nearly two years, to meet face-to-face, discuss and potentially formulate partnerships and business propositions for the future. The entertaining conference concluded with a view to returning again in the next year, hopefully when the world has made even more progress along the exhausting road to recovery.
Returning live and in-person, the Offshore Well Intervention Gulf of Mexico 2021 conference treated assembled industry stakeholders to an informative two-day exploration of the state of well intervention in the region and examined the technology and best practices which have the potential to shape campaigns of the future.
Jim Maher, President of Trendsetter Vulcan Offshore (TVO) who co-chaired day one of OWI GOM 2021, opened the conference by noting his delight at finally being able to speak to everyone in person and emphasised that “times of great dislocation, which these clearly have been, are often the times where most innovation comes to the fore.
“As the market recovers, the intervention technologies are among the most viable as they are the closest approximation to short cycle. As we start going again, intervention technologies are certainly going to be among the most competitive for the capital available.”
Following this, over the course of the next two days, attendees were treated to a banquet of engaging sessions featuring presentations and discussions from the most influential service providers, operators, consultants, and more.
BP lead a panel discussion on how the company achieved optimal results on its ongoing RLWI campaign (which began two years ago) and the challenges it has faced and how they will continue to overcome them. Representatives from C-Innovation, Halliburton and JDR Cable Systems joined the discussion and together they explored the innovative tools, equipment and technology which could be deployed in order to achieve the most efficient intervention campaigns.
The implementation of new technology was one of the conference’s clear themes, which Charles Brooks, Technical Sales Representative from Interwell, heavily leaned into as he presented on the Interwell Barrier Verification System. This market-leading barrier assurance tool provides, as demonstrated by a case study from the GOM, time efficiency, confident and correct verification of well barrier and integrity, the ability to reduce tensile stress from pressure from pressure testing from surface (especially in fragile well constructions) and more. This solution was quoted as the most extensive downhole barrier verification the operator has performed in the region, proving its quality.
Maxim Volkov, Principal Domain Champion at TGT Diagnostics, followed closely on Brooks’ heels by introducing the Sand Flow product which precisely locates sand entry to the wellbore and provides a qualitative sand count, indentifying problem zones to help combat the serious issue of sand production. Through the use of case studies, Volkov demonstrated how the Sand Flow product, when used in tandem with Tendeka’s Filtrex solution, can localise target and fix sand issues affecting wellbores to ensure productivity is restored and integrity is maintained.
Not to be left out, Archer joined the party as Kevin Squyres, Sales and Service Delivery Manager, demonstrated the capabilities of the Stronghold Barricade, Defender and THOR solutions which can eliminate the need for milling, providing an effective alternative to traditional methods of plug and abandonment.
While new technology can bring value, it is also important to understand and asses the risk of incorporating it into intervention campaigns. This topic was covered in detail by industry experts from Schlumberger, United Subsea Specialists, Chevron and CRG Oilfield Abandonment LLC at the session focused on intervention technologies for existing field uplift.
In the following sessions on day one the sessions were dedicated to:
• Understanding the considerations when evaluating different intervention philosophies and technologies. A Baker Hughes presentation highlighted that light well intervention can achieve substantial benefits such as 55% total emissions reductions (when compared to a rig-based operation) as well as cost-saving incentives.
• The consolidation of well opportunities, where representatives from Trendsetter Engineering, BP, MADCON and TGT Diagnostics presented case studies of campaigns that have increased production and extended the profitable life span of wells as well as explored the future opportunities presented by LWI, HWO and coiled tubing technologies.
• Considering lifecycle completion. Shell, BP, PRT Offshore and Welltec associates discussed the completion design considerations; new completion and well technologies which could have an impact on the future well intervention scope; and how regional operating environment influences operations view’s on new well programmes.
• The successful application of real-time enabled coiled tubing for abandonment of a deviated well with complex anomalies. Ed Adams, Customer Engagement Coordinator at Schlumberger showcased a case study on a tricky well which was causing issues for the operator. Schlumberger deployed the ACTive CCL to detect tubing anomalies and implemented a number of solutions to return the well to safe state which was all done in days before hurricane Elsa entered the GOM.
The day was closed with a brief review of the enormous amount of material that was covered with topics such as marketing dynamics, creating value in well intervention and technology and operation considerations in particularly standing out. Before the attendees retired to the networking drinks, they looked ahead to day two and the exciting subjects that were yet to be explored.
Kongsberg Digital has confirmed that Heerema Marine Contractors (HMC) has renewed its Long-Term System Support Program (LTSSP) contract with the company for another five years.
The LTSSP is in support of a K-Sim Offshore Crane simulation system, which features digital twins of HMC’s semi-submersible construction vessels, ships and barges.
Renewal of the LTSSP ensures Kongsberg Digital’s continued commitment to maintaining Heerema’s simulators at the leading edge of available technology. Installed in 2015 as one of the world’s most advanced offshore heavy lift crane simulators, its usage ranges from confirming feasibility of new methods and equipment to optimising efficiency and safety performance for current execution methods.
“By renewing this LTSSP we are ensuring that our clients, offshore crew and project teams continue to benefit from the most advanced simulation-based training and project preparation on the market, simulating real-world scenarios,” commented Jan Pieter de Vries, Manager Simulations and Visual Products, HMC Academy. “Kongsberg Digital have proved a competent partner, working in close collaboration with the team here at HMC to ensure that training and simulation needs are met. We are pleased to confirm our ongoing relationship.”
Heerema’s simulator platform was developed specifically by Kongsberg Digital to meet Heerema’s requirements as a leading marine contractor in offshore renewables and oil and gas, specialising in transporting, commissioning, and decommissioning offshore facilities.
The Simulation Centre is a real-time offshore environment where offshore crew and project teams examine all project aspects and associated risks. It includes two offshore crane operator domes and a bridge with K-Sim DP simulator, based on the same Kongsberg Maritime K-Pos DP systems used on HMC’s vessels. Detailed models of Heerema’s SSCVs, Heavy Lift Vessel, tugs and barges ensure realistic scenarios and enable detailed pre-mission training for heavy-lift projects.
“HMC’s renewal of this LTSSP is a clear endorsement of the capability and longevity of our maritime simulation solutions,” remarked Andreas Jagtøyen, Executive Vice President Digital Ocean, Kongsberg Digital. “Our commitment to supporting the maritime industry is not limited to providing the best technology, but also extends to ensuring that our customers gain value from their investment for years to come, through long product lifecycles and extensive service, provided by our 24/7 support network. Our LTSSP programme elevates our relationship with our customers beyond just being a vendor to rather act a trusted partner.”
Helix Energy Solutions Group, Inc, an international offshore energy services company, has joined Trendsetter Engineering, Inc. in a global partnership to provide integrated hydraulic intervention services for subsea wells and flowlines.
The new partnership will integrate Trendsetter’s 15,0000 psi Subsea Tree Injection Manifold (15K STIM) and experienced personnel into Helix’s state-of-the-art fleet of well intervention vessels including the Q4000, Q5000, Q7000, the Seawell, the Well Enhancer as well as two chartered monohull vessels; the Siem Helix 1 and the Siem Helix 2.
Mike Cargol, VP of Rentals and Services for Trendsetter Engineering, commented, “This collaboration with Helix allows us to streamline contracting, improve operational efficiency and mitigate the operational and financial risks typically associated with hydraulic intervention operations. Although the initial focus is hydraulic intervention, we are excited about what the future holds for Helix and Trendsetter and look forward to collaborating further in order to provide additional value-added services to our clients.”
Jonathan Rourke, General Manager of Helix’s Subsea Systems Intervention Group, added, “We are delighted to have reached this agreement with Trendsetter Engineering, representing a collaboration between two industry leaders with expertise, experience and capabilities in the global well intervention market. This partnership will expand Helix’s intervention capabilities to further provide cost-effective and efficient alternative solutions to our end clients, and further reduce financial risks.”
For the 7th edition of the Offshore Well Intervention Conference Gulf of Mexico, focus is turning to well intervention optimisation through innovative technologies in order to build a best-in-class workover strategy that suits the changing market.
Bhargava Ram Gundemoni, Global Solutions Specialist at 3M, presented at the OWI GOM virtual webinar in the lead up to the conference and revealed how his company’s innovative solution, the Ceramic Sand Control system, can allow operators to enhance their oil and gas production and increase productivity and profitability, ensuring a reasonable balance between OPEX and EOR to create value and yield.
Ram showcased field proven Ceramic Sand Screens technology with three case studies, revealing how different operators achieved a simplified sand control and the general key performance drivers in sand control selection by reducing equipment and personnel footprint, risk reduction to enhance safety and durability and finally, operational excellence - for increased productivity and increased return on investments.
Challenges and current market needs
The general market needs are to increase productivity for less cost and achieve less risk. Traditional practices used for the Sand Control Selection (SCS) process are based on mature technologies and methodologies that often fail to meet the key performance drivers. Mature technologies often rely on a metallic filter media which is used as the mechanical sand control barrier downhole. Metallics filter media metrologically has erosion limits that constrict the boundary condition of hydrocarbon productivity. If a more erosion resistant filter material can be utilised, the upper safe operational window can be extended limiting the risk of erosional failure and hot spotting of the downhole sand control system whilst optimising asset recovery where possible. In addition, offering greater longevity to downhole sand control through a material change reduces the reported millions of dollars companies employ in repairing wells with failed sand control.
Disrupting the traditional sand control approach
The solution is a change of metallic filter media to ceramic filter media of the screen. This has been achieved by integrating a full-body ceramic part in the form of rings on a pre-perforated base pipe on to which ceramic rings are stacked and hold with two end caps and with an external shroud on top. The stack of ceramic rings creates a slot opening which is designed for the application spec-in and the ceramic material at the inflow offers erosion resistance and therefore mitigating the hotspotting potential ‒ allowing the operator a wider operating window of productivity.
Ceramic Sand Screens have been proved by deployment in the industry both in green fields and in intervention wells, delivering operators operational simplicity, Reduced HSE Risk at lower Capex delivering higher productivity. In some cases, Ceramic Sand Screens has been an enabling technology to unlock production potential with faster return on investments.
Standardised field-wide approach with simplified stand-alone screen sand control
Ceramic Sand Screens unlocks the operator methodology to achieve a simplified and standardised sand control approach in wide range of reservoir conditions and well architecture as downhole sand control system in OH, cased hole on a rig or through tubing rigless applications. Ceramic Sand Screens have been deployed and delivered success in 120+ applications with homogenous, heterogeneous, well-sorted to poorly sorted, low to high fines reservoir of sand properties.
Ceramic Sand Screens are being utilised as an asset wide standard solution to stop proppant flow back in a stimulated well completion.
To learn more about this solution and the advantages it can offer for operators, Offshore Network sat down for an in-depth chat with Ram:
How does ceramic sand screen add value to hydraulic stimulated wells?
“In a hydraulic frac stimulated well completion method, proppant flow back is a challenge. If this is not controlled results in erosion of tubulars, Health Safety and Environment (HSE) issues to potential leak eventually leading to spills. Operators also face economical losses due to prolonged clean up phase post stimulation (additional rig cost due to stand-by) and increased erosion risk to the well jewellery during clean-up. The Ceramic Sand Screens offer an economical approach to dealing with proppant flowback either using rig or rigless deployment methodology.”
“We are offering the opportunity to deal with proppant mitigating the need of resin-coated gravel and in some instances need of gravel packing in stimulated wells. With our solution, the operator has flexibility to use a rigless approach to stimulate/ frac the required zone and then run ceramic sand screens on wireline/ slickline to set across the stimulated zone. The ceramic material is extremely hard in nature offering high resistance to hotspotting and erosion caused by high strength proppant material. This will protect against proppant production topside and restrict equipment from being damaged higher up. In addition to cost-saving and HSE benefits, much less energy is required for deployment, which means the operator leaves less of a carbon footprint by reducing the need of rig."
How this technology can be further utilised in conventional sand control applications by operators to gain value and unlock production potential from their existing standard well stock?
“Not only in stimulated wells, but ceramic sand screens have also extended the traditional operational envelope of ‘Stand-a-Alone’ screen application, proven in unconsolidated sandstone formation. This technology has enabled operators to unlock production potential utilisng less complex rigless deployment technique. There are many wells globally shut-in due to traditional primary sand control failures. Many thin bed reservoirs which are left behind the casing are uneconomic using a rig-based approach. Simplified Sand control methodology with Ceramic Screens can add additional cumulative hydrocarbon production from the existing well stock via an economic satisfied solution.”
Focusing on the upcoming OWI GOM conference, could you explain what operators in USA can take away from this technology to add value to their oil and gas producer fields in Gulf of Mexico?
“In the Gulf of Mexico, operators can adapt their approach with this enabling proven technology to add incremental value to their assets. This approach fits in nicely with the energy trends in the industry, especially in particular the industry thirst in looking at more effective way to address the challenges of ensuring operational excellence. Our solution is simple, flexible, can be implemented rig or rigless and can still yield high productivity proven globally.”
As of 29 September 2021, 3M has completed 121 installations for sand control with users globally consisting of 50% oil producers and 50% gas producers. The product also been qualified in alignment to ISO 17824 / API 19SS Standards.
To learn more about Ceramic Sand Screens, visit https://www.3m.com/3M/en_US/oil-and-gas-us/ceramic-sand-screens/
If interested in such a simplified solution to unlock the production potential assets by addressing sand control challenges, contact Bhargava Ram Gundemoni:
To best meet customer needs, you must be a solution provider, not just a product provider. Parker LORD’s attitude is, and has always been, to collaborate with customers to find an approach that meets their needs quickly and easily.
They have proven this mindset yet again by finding a better process for working with customers on gimbal assembly design.
Parker LORD gimbal pads and assemblies for offshore oil rigs and intervention vessels are designed under strict process and quality controls to ensure each part performs consistently. They can accurately and dynamically model the stiffness of any gimbal system in any plane of rotation. A step beyond competitors, this new tool incorporates feedback from customers in real time to create tailored solutions. The result is a product designed to handle extreme loading and environmental conditions for improved pad life.
The flexible design tool introduces a process unprecedented for the oil and gas industry, creating solutions through working closely with the customer, instead of only using existing catalog parts. Traditionally, the customer and supplier might have limited interaction during the ordering process. Using this flexible design tool, placing an order becomes a collaborative partnership where Parker LORD engineers and the customer work together to solve problems. Additionally, the tool can accommodate design changes dynamically, allowing for multiple design versions.
To make this work, the first things Parker LORD want to know about a customer’s gimbal assembly is how it is intended to be used, the range of expected limitations and the maximum stiffness needed. From there they work together to produce a solution.
In one example, this fast-moving live design process allowed them to identify, analyse and quote four different systems as the project scope changed over a three-week period. The customer was struggling with how to add a much-needed gimbal assembly to an existing bid and through these conversations they created a solution that was within budget.
The design tool allows system level rotational stiffness calculations in any direction. This graph below shows the relative pad positions and corresponding system rotational stiffness in each plane from center. Asymmetric, or non-uniform spacing can also be evaluated using this tool. 
It takes innovation to work on a solution. Sometimes the solutions can involve renting a part instead of buying it or designing a part to specifications that will then bring it into budget. The market collapse is forcing rig and vessel operators to think differently. Flexibility and elegance around the design are now key.
Fill out this form and a member of Parker LORD’s engineering team will contact you to talk through how their flexible design tool can help you when ordering your next gimbal assembly.
Learn more about the new Parker LORD flexible design tool at https://www.lord.com/industries/oil-and-gas/offshore/drilling-rigs/gimbal-bearing-assemblies-and-pads
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