With more and more producing fields showing late life symptoms like aging well stocks and high water cut, which can lead to well integrity issues, Hemant Kumar, Technical Advisor for Production at Halliburton, explained why well integrity management is becoming more important than ever.
Many gas fields report high CO2 and H2S content which can be challenges for pipe metallurgy and reliability. Faced with increasingly stringent regulations, a shrinking experienced workforce, and the need to control costs, E&P operators are getting serious about well integrity management (WIM).
Path to better well integrity management performance
DecisionSpace Well Integrity Management software is designed to help minimise risks and associated production losses by streamlining well integrity monitoring and analysis. With automated and integrated workflows, it delivers rapid diagnosis of well barrier elements to spot well integrity risks faster and execute preventive and remedial maintenance in time. It helps end users in rapidly identifying high-risk wells, taking corrective actions faster, and mitigating issues to maximise well availability.
Integration with WELLCAT software gives DecisionSpace Well Integrity Management software a better ability to detect the down hole integrity risks early on and help prevent downtime or environmental hazards. “Over 80% of the operators globally trust WELLCAT for its advanced engineering calculations required for well design,” Kumar added.
Workflows in DecisionSpace Well Integrity Management software automatically fetch engineering calculations to continuously update the Stress and Load envelopes of the tubulars and alert end users if actual operating conditions of the wells trend closer to those envelopes. Kumar said this approach gives end users a better understanding of how changing operating conditions impact the integrity of the wells, which is not always possible with the simple MAASP-based operating envelopes.
Flexibility for customisation
DecisionSpace Well Integrity Management software is built on the E&P industry’s fully open, interoperable DecisionSpace platform which offers E&P companies flexibility for customisation and the ability to create well integrity management solutions tailored to their unique business processes and IT environment.
Any WIM software needs to work in a heterogenous technology environment. It needs to talk to a multitude of data sources and adjust to changing modes of operations or expansion. An inability to adjust adds to architectural complexity and cost of ownership, and E&P companies may need to procure additional technologies to keep up with the growing needs of their business.
The underlying DecisionSpace platform connects with a variety of data sources and accommodates evolving workflows, visualisation, and analytical needs without requiring additional technologies. The platform is the foundation to all Halliburton’s digital offerings and is supported by long-term product roadmaps and R&D investments. With a track record of successful implementations globally, it brings to E&P companies the assurance of referenceable quality and future readiness.
Helix Energy Solutions Group, Inc. has been awarded a field decommissioning contract by Trident Energy do Brasil (Trident Energy).
The project, located offshore Brazil in the Pampo and Enchova Clusters in the Campos Basin, is expected to commence in late 2022 for a firm period of 12 months with options to extend.
Helix will provide a riser-based well intervention vessel (either the Siem Helix 1 or Siem Helix 2); a 10k Intervention Riser System; project management and engineering services; and, in conjunction with Helix’s Subsea Services Alliance partner Schlumberger, fully integrated plug and abandonment well services.
Trident Energy owns and operates four platforms in the Campos Basin, and its Brazil operations are part of a global organisation backed by Warburg Pincus with a stated focus on operating and redeveloping mid-life oil and gas assets.
Scotty Sparks, Helix’s Executive Vice President and Chief Operating Officer, commented, “We are pleased that Helix has been awarded this major decommissioning contract. This is another step forward in the execution of our strategic objectives which include diversifying our client base in the region while continuing to provide best-in-class and global leading decommissioning services. We look forward to developing our relationship with Trident Energy.”
Daniel Stuart, Helix do Brasil’s Director of Operations, added, “Our rigless well intervention services offer a lower cost and lower greenhouse gas intensive solution for decommissioning offshore wells compared to rig alternatives. We believe that delivering this milestone field decommissioning project will support future growth in the region, and lead to additional opportunities.”
Baker Hughes has expanded its presence in Guyana by opening a new local supercentre facility for oilfield services and equipment.
Spanning more than eight acres, the supercentre will support regional customers and bolster Baker Hughes’ localisation efforts within South America.
In the country, the company currently provides drilling services, drill bits, and drilling and completion fluids to several drilling rigs, with its completions and wellbore intervention product line supporting all upper completions for development wells in Guyana.
Baker Hughes’ Turbomachinery & Process Solutions (TPS) and Upstream Chemicals businesses also provide technology and solutions to the second floating production, storage and offloading (FPSO) vessel in Guyana, known as Liza Unity as well as other projects in the region.
The supercentre has been built together with Baker Hughes’ existing completion warehouse and liquid mud and completion fluids plant, providing full support to customers in Guyana and Suriname. It represents a multimillion-dollar investment from Baker Hughes over 15 years and includes a workshop, warehouse, and laydown storage yard including maintenance facilities and equipment.
The facility is expected to employ more than 100 employees within five years, and the majority are expected to be Guyanese.
“This announcement significantly expands Baker Hughes’ ability to support Guyana’s energy goals and its leading oil and gas projects,” said Maria Claudia Borras, Executive Vice President for Oilfield Services at Baker Hughes, during the facility’s opening ceremony.
“Baker Hughes is well-known in the region for service and technical excellence, and our new Guyana supercentre will bolster our efforts to expand even further into the evolving market. We are proud to be here, and we look forward to this exciting next phase in our work.”
EnQuest, a production and development company, with operations in the UK North Sea and Malaysia, has provided an update on its operational performance, decommissioning business and for the year 2021.
The company also reported that its debt reduction continues with strong cash flow and improved macro conditions.
EnQuest chief executive, Amjad Bseisu, commented, “Our decommissioning business performed better than expected, while our emissions were 45.7% below the North Sea Transition Deal 2018 baseline, and close to the 2030 target of 50%. I am very pleased we are industry-leading in emission reductions and am excited about our new energy initiatives around Sullom Voe.
“The supportive macro environment and higher oil prices allow us to look forward to organic growth to offset natural declines. We remain focused on continuing to reduce our net debt while selectively investing in our low-cost, quick payback well portfolio. At the same time, we will continue to be disciplined with respect to M&A opportunities.
“EnQuest’s business is strongly positioned to play an important role in the energy transition. We will do so by responsibly optimising production, leveraging existing infrastructure, delivering strong decommissioning performance and exploring new energy and further decarbonisation opportunities.”
The company also reported that during the year, a production enhancement programme, including a coil tubing intervention campaign was undertaken, restoring four wells to production. Repairs to a compressor gearbox failure which resulted in single train operations during much of the fourth quarter of 2021 were completed and both trains are now in operation.
Brazilian state-run oil company Petrobras has opened a public consultation to obtain information from suppliers on alternative technology for retrieving flexible pipelines in the Marlim field, off Brazil’s southeast coast.
According to the state-run oil firm, the service to be hired is particularly challenging because some of the pipes that lie 1,250m under water do not have the necessary structural strength to guarantee their retrieval.
That is, under the premise that the pipelines would not support their own weight under a catenary (curves forming a U shape) equivalent to or close to the water depth in which they are installed, they must be retrieved using a resource or tool that is submerged to the proper water depth.
The tool must avoid dredging the seabed and not come in contact with any equipment that may be installed there, remaining at a minimum distance of 30m from the seabed.
The recovery must be done by a reel system within the standard used by Petrobras in its operational bases. In addition, there is a need to use smaller vessels, such as ROVs (remotely operated support vessels), for example, as there are currently a reduced number of operational bases that support vessels of the size of PLSVs (pipelay support vessels).
A possible solution proposed by Petrobras comprises a recovery method consisting of descending a reel drive system to a fixed distance from the seabed, close to 50m (enough to avoid colliding with obstacles and subsea systems), therefore minimising the catenary generated during the recovery.
The completion and submission of the public consultation, with the title ‘Subsea Reel Drive’, must be done by 4 March, 2022.
Located in the Campos basin, the Marlim field is going through a revitalisation process, which encompasses the installation of two new FPSOs (Anita Garibaldi and Anna Nery) and the decommissioning of several production units (P-18, P-19, P-20, P-26, P-27, P-32, P-33, P-35, P-37 and P-47) and associated subsea equipment.
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:
Global Maritime has recently completed the Marine Warranty Scope (MWS) for decommissioning the LOGGS Complex in southern North Sea.
The five platforms, linked by bridge, were removed with Saipem vessel S7000 and were supported by the North Sea Giant.
All of the jackets, topsides and bridges have been transported to Able UK, Hartlepool, where they will be dismantled and recycled.
Robert Askins, London Operations Managers, commented, “Global Maritime are delighted to achieve this significant milestone. Working collaboratively with the client to complete this complex decommissioning campaign safely and efficiently is a testament to our strong working relationship.”
Esso Australia, a subsidiary of ExxonMobil Australia, has entered into a multi-year agreement with DOF Subsea to charter a Multi-Purpose Supply Vessel for the support of its decommissioning activities in Bass Strait.
Dylan Pugh, ExxonMobile Australia Chair, said that the subsidiary is committed to safely decommissioning the Bass Strait offshore facilities and over the last few years has completed around US$600mn of early decommissioning works in the strait, including removing the Seahorse and Tarwhine facilities, completing P&A activities on Blackback and Whiting wells, and making significant progress on Kingfish B and Mackerel.
“As we continue to progress these important, early decommissioning works, we are also planning for the eventual decommissioning of our facilities that are to cease production in the near future,” Pugh commented.
The DOF Subsea vessel is expected to arrive in Bass Strait in the middle of 2022 where it will support early decommissioning works on the Perch and Dolphin facilities before moving onto other topside and subsea work scopes.
Pugh added, “We continue to assess new projects in Bass Strait with the aim of extending our production of Gippsland gas into the next decade.”
“Just last year we commissioned West Barracouta, one of the largest domestic gas projects this decade. As it showed, there is still potential left in Bass Strait and we are working hard to unlock its full value so we can continue to deliver the gas Australians need.”
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.”
Innova AS and Teledyne Energy System Inc. have demonstrated how hydrogen can be used for local power of subsea control systems.
Teledyne’s Subsea Fuel Cell Supercharger is a hydrogen and oxygen fuel cell electric power source designed to operate on the ocean floor with no connection to the surface. It is inherently load following and provides power on demand. The subsea hydraulic power unit (sHPU) developed by Innova provides control fluids, grease and chemicals for different subsea application at a pressure up to 690 bar.
The demonstration included a well intervention simulation in which the Subsea Supercharger powered the Innova sHPU. The two systems were integrated and effectively deployed to a depth of 235 metres (770 feet) where a low viscosity fluid was pumped to a pressure of 180 bar (2,600 psi) for 30 minutes, six times a day.
The Subsea Supercharger transitioned from ‘Sleep-mode’ to ‘On’ in response to power demands from the sHPU as it repeatedly cycled on and off.
The system was designed to provide the offshore oil and gas community with an environmentally responsible backup power alternative for failing umbilical power sources as well as untethered power for green field development or brown field sustainment. It is also capable of powering resident ROVs, providing energy for autonomous underwater vehicle (AUV) charging docks, back-up power for subsea control systems, and supports transition to green hydrogen from fossil fueled surface-based systems.
The demonstration took place at the Norwegian Center for Offshore Education, Tau Autonomy Center in Tau, Norway. The next validation test will occur in the spring of 2022 and will incorporate the Subsea Supercharger with an AUV charging dock to demonstrate untethered, long-duration AUV operations.
Tendeka offers its portfolio of innovative tools and technologies in sub-Saharan Africa to restore production from existing well stocks, reduce gas and water flow and improve production.
The versatile suite of solutions does not require complex interventions and has already brought huge logistical, technical and financial savings to operators in the region.
Intelligent technology
PulseEight dynamic downhole reservoir management system is the world’s first re-deployable wireless completion range. Utilising Fluid Harmonics telemetry, two-way communications to and from a suite of downhole tools can be used to optimise production:
• PulseEight Electronic Ambient Valve (EAV) reinstates wells which were previously closed through loss/lack of a safety valve
• PulseEight Wireless Gauges (WG) provides pressure and temperature data from wells which have lost permanent systems or where these were never installed
• PulseEight Intelligent Valve (ICV) delivers infinite, inline manipulation of flow for choking and shut-off purposes
In addition to PulseEight, the company’s Mature Fields offering includes retrofittable, next generation inflow control technology, to attain a uniform inflow profile for enhanced oil production in new wells or through intervention.
Tendeka also offers in-house capability to custom design a range of sealing solutions, from non-standard diameters to unique fluid parameters, ensuring a perfect fit for well projects.
These include SwellStack sealing solutions which are rated to 15,000 psi in gas, reinstating the function of safety valves quickly and effectively; Swellable O-rings to reinstate the function of safety valves quickly and effectively; and SwellRight Side Pocket Mandrel (SPM) Plugs to provide pressure integrity in damaged side pocket mandrel bores.
Following success in Chad to solve sand production issues in water injection wells, Tendeka is working with a local partner in Nigeria to deliver Casacde3 in a multi-well subsea development.
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:
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