Halliburton, a leading provider of products and services to the energy industry, has announced the implementation of the Auto Pumpdown service within the company's hydraulic fracturing business which enables wireline and pump automation during unconventional completions operations.
The Auto Pumpdown service controls fluid pumps and a wireline unit as a single, fully automated, closed-loop system to maximise Halliburton’s plug and perforating performance and efficiency. The system executes operations to plan and optimises equipment operation for improved consistency.
The service enhances operations by automating tasks previously prone to human inconsistencies and reduces risk by providing prompt feedback to dynamic downhole conditions. These improved consistencies create more efficient operations and reduce required fluids for tool conveyance.
Chris Tevis, Vice President of Wireline and Perforating, Halliburton, commented, “Halliburton’s Auto Pumpdown service ushers in a new era of intelligent plug and perf operations that reduce risk while redefining the level of efficiency and consistency we provide our customers. The service reinforces our leadership in unconventional perforating services by minimising variability in operations, which helps avoid unnecessary and costly well interventions and simultaneously improves efficiencies.”
Multiple perforating crews in North America currently use Auto Pumpdown service. Here, it has demonstrated improved operating efficiencies, reduced fluid requirements, and reduced risk of unnecessary well interventions.
Halliburton will implement Auto Pumpdown service on its North America fleet through 2023 and beyond.
Onshore seismic acquisition and imaging experts, STRYDE, has enabled five new geothermal projects in Q1 of 2023 with the supply of its low-cost seismic technology, with a further five contracts for scheduled to commence during Q2.
The global contracts, equating to a six-figure sum, will see the company’s technology deployed across the US, Middle East and Europe.
Two of the ten contracts include nodal equipment supply and seismic data processing for STYDE’s largest geothermal project to date in the Middle East, as well as a European survey that was constructed alongside a geological research centre in Belgium. Five of the seismic surveys have already commenced, and all ten are expected to be completed by the summer of 2023.
Nick Tranter, STRYDE’s Business Development Manager for New Energy, said, “Within the renewable energy space, STRYDE presents a cost-effective and reliable solution to help geothermal operators de-risk investment decisions, with high-resolution seismic data.”
Mike Popham, STRYDE CEO, commented, “I am proud to have STRYDE play a part in supporting the energy industry transition towards net-zero. Our technology has proven to be a key tool in propelling more than 20 geothermal projects to date, by providing an economically viable solution for understanding and monitoring the subsurface.”
Neptune Energy has announced an agreement to create new ‘digital twins’ of two offshore platforms in the Dutch North Sea, expanding its portfolio of digitised assets to 14 in total.
The twins will enable engineers to carry out traditional offshore work from an onshore location, accelerating work schedules and reducing costs. UK-based 3D technology specialist, Eserv, will digitise the Neptune-operated D15-A and K12-C platforms, after previously creating digital versions of 12 platforms in the Dutch and UK sectors.
This technology allows Neptune teams to virtually visit assets, leading to thousands of hours of work being completed from office-based locations since the twins were introduced.
Neptune Energy’s Director of Operations for the Netherlands, Stephane Lacote, said, “The use of 3D technologies such as digital twins have provided significant benefits including reducing operational costs by enabling traditional offshore activities to be completed quickly and efficiently, without travelling offshore.
“Our engineering teams can now virtually visit platforms to support the safe running of operations from anywhere on the planet.”
Digitising operational assets to improve safety and productivity, as well as reduce environmental impacts, supports Neptune’s aims to enhance asset integrity and provide employees with technologies that support collaboration with colleagues globally.
Saipem has been awarded three new offshore contracts along with two competitive FEED contracts totalling approximately US$650mn.
The first of the contracts was assigned by Azule Energy for the Agogo Full Field Development project – a deepwater greenfield development approximately 180 km offshore Angola. The contract encompasses the Engineering, Procurement, Construction and Installation (EPCI) of rigid Pipe-In-Pipe flow lines with associated subsea structures. Saipem will mobilise its state-of-the-art offshore installation vessel FDS2.
The second contract was awarded by EnQuest for the decommissioning of existing infrastructures in the Heather oil field located in the UK sector of the North Sea, around 460 km northeast of Aberdeen. Saipem will carry out the engineering, preparation, removal and disposal of the upper jacket of the Heather platform, utilising the semisubmersible crane vessel Saipem 7000.
The third contract was issued under the Aramco LTA programme in Saudi Arabia, where Saipem will execute the offshore EPCI of one platform topside and the associated subsea flexible, umbilical and cable system.
Additionally, Saipem has been awarded two Front-End Engineering Design (FEED) Competition contracts for gas developments projects. The first one, assigned by Shell Trinidad & Tobago Ltd., is related to the development of the Manatee natural gas fields. The other contract concerns the development of the upstream facilities to feed the natural gas PAPUA LNG project in Papua New Guinea.
All of the above further consolidates Saipem’s position both geographically and in key segments for the offshore business, in particular in decommissioning where the company boasts an impressive track record.
Archer has announced the completion of the Baker Hughes’ UK Coil Tubing and Pumping business acquisition made in February 2023.
Dag Skindlo, CEO of Archer, said, “This acquisition is part of our strategy to be one of the leading well services companies in the UK. Together with our well-established platform operations business, Archer is uniquely positioned to serve our customers with a broad range of production enhancements and P&A operations. We are pleased to welcome this highly skilled and experienced team to Archer and look forward to adding value to existing and new customers.”
Following new developments to the Decommissioning and Abandonment Australia 2023 programme, Offshore Network has released a revised agenda.
More than 250 decommissioning experts are expected to attend this year’s D&A AUS conference, being held at the Duxton Hotel, Perth, from 30-31 May. As the country’s largest decommissioning summit, attendees will receive unique access to updated regulatory guidelines, innovative technologies and valuable lessons which contribute to the success of upcoming campaigns.
With the forthcoming decommissioning wave more visible than ever, D&A AUS 2023, like its predecessors, will serve as a meeting point for the industry to get ahead of the challenge and unlock the opportunities held within. Now, there is more incentive to join the community in Perth this year, with new presentations and tech displays added to the agenda.
Notably, Craig Baxter, Decommissioning Technical Manager from Claxton Engineering will present on innovation and collaboration in underwater laser cutting, allowing attendees to access insights into the tools capabilities and understanding of where the technology can be utilised best.
Visitors will now also be looking forward to a presentation from Richard Bazen, Sales Director of Energy from RemSense. At the conference, Bazen will look at mitigating the risk of HSE and decommissioning liabilities using photogrammetry based digital twins. With the digital age firmly upon us all, this is one session not to be missed.
Offshore Network has now announced additional facets with AF Offshore Decom presenting and Trident Australia exhibiting at the conference. Furthermore, the organiser has revealed group bookings from Woodside, Santos, Weatherford, Mann Group, Tetra Tech and more.
Find all relevant information and the agenda in the brochure here: https://offsnetevents.com/da-aus/
Or contact:
Erin Smith
Global Accounts & Australasia Regional Manager
Offshore Network Ltd.
t: +64 (0) 3 569 3074 | e:
The team of AIS Survivex, an offshore training provider in the UK, has received an insight into life on board a decommissioning rig courtesy of Well-Safe Solutions.
Members of AIS Survivex were invited on board the Well-Safe Defender to let them experience life on a bespoke well plug and abandonment semi-submersible rig which accommodates 110 energy workers. It was described as an enlightening experience which allowed the team to understand more about the working conditions and challenges for the people they help train. AIS Survivex has been delivering and managing all training for Well-Safe since 2019 and is currently carrying out a range of training to prepare the Well-Safe Defender’s crew for its forthcoming campaigns.
The rig itself used to be used for drilling operations in the North Sea but, since being taken into Well-Safe’s ownership in 2022, has been converted to play a part in the energy transition as a bespoke well decommissioning asset. Currently, the rig is undergoing a host of efficiency enhancements ahead of its mobilisation this month for a well P&A campaign with Spirit Energy on the Trees and Chestnut fields.
laire Adams, Training and Competency Advisor at Well-Safe Solutions, commented, “With over 360 staff working for Well-Safe Solutions, we are focused on safe, smart and efficient delivery of well plug and abandonment – and all of this begins with effective training. AIS Survivex have supported Well-Safe Solutions on multiple occasions by providing multi-skilled trainers to provide rig-based training on all our assets as part of our rig readiness plans.
“Two AIS Survivex multi-skilled trainers were delivering a suite of courses to our crew onboard the rig to enhance personnel and team compliance against our matrix. The input of the AIS Survivex trainers is paramount in ensuring the relevant Well-Safe Solutions personnel held the correct training certification to ensure operational compliance prior to the rig mobilising for its upcoming P&A campaign with Spirit Energy. Collaborative working is key to our success and a safety-first mentality is critical for offshore workers.”
The spread consisted of a Horizontal Lay System (HLS) with the TTS-4/140 Series Tensioner, and a Generation 3 Reel Drive System. The scope covered recovery and installation of umbilicals and flexibles as part of an FPSO replacement. The project was part of the field’s infrastructure upgrade, aiming to reduce operational costs while increasing storage capacity and extending the production life.
The flexible products were handled through the vessel’s moonpool, enabled by the MDL HLS. The highly compact system allowed for efficient mid-line connections, by allowing safe and convenient hang-off for the product’s end terminations.
The integration of reel cradles and lashing points within the RDS track system facilitated quick mobilisation and demobilisation of the reels, as it eliminated the requirement for welding down cradles and reduced the requirement for pad eyes on the vessel desk.
As part of the scope, MDL also delivered the full sea-fastening design for the client’s back deck and provided materials and fabrication support to complete the mobilisation.
Euan Crichton, Project Manager at MDL, said, “This was an exciting project for MDL, partly due to the new location which grows further our West Africa track record, but also because of the short timescales the client was working to. For the Skandi Contractor, our compact systems proved to be the optimal solution. The HLS, tensioner and Generation 3 RDS make up a highly capable spread, enabling multi-reel installation over the moonpool.
“We are continuing our support to DOF in various global locations, configuring bespoke equipment spreads suitable to their vessels. So far, the open communications between the two companies have helped us zero in on the most efficient approaches to lay and retrieval scopes, to deliver maximum value.”
Jadestone Energy plc, an independent oil and gas production company headquartered in Singapore, has announced the Montara Venture FPSO offshore Australia restarted production operations last week.
Following what the company called a ‘carefully planned’ restart programme, production recommenced from the H6 well within the Montara field, with further wells set to follow, including the first Skua subsea well.
With the systematic opening of additional wells in line with the restart plan, production rates are set to increase, and the company will announce its production guidance for 2023 once output has stabilised.
Paul Blakeley, President and CEO at Jadestone Energy, said, “I would like to thank everyone in Jadestone who has contributed to the safe and successful restart of Montara operations as well look forward to putting this challenging period behind us and returning to business as usual.
“It is a relief to see operations at Montara being restored and we look forward to increasing production and cash flow. We also plan to return to growth, having completed three acquisitions within the last six months, with several new acquisition opportunities in the pipeline.”
The restart programme was instigated after the initial shutdown of production in July 2022 after a small leak from the crude oil tank aboard the FPSO was detected and required permanent repair.
Decom Engineering’s specialist cutting technology has been successfully deployed on a decommissioning project in West Africa.
The C1-24 chop saw was deployed in water depths of up to 1,050 m as part of an operation to recover a jumper connector on behalf of Total Energies in the Gulf of Guinea, offshore the Democratic Republic of Congo.
The work scope included the cutting of the insulated 6” Duplex flowline at each end of the jumper, with the chop saw deployed by ROV with hot stab capability, and using a Tungsten Carbon Tip blade.
The C-1 chop saw range is certified for use in water depths of up to 2,000 m, and has multiple buoyancy options, hot stab integration, blade reverse capability and bespoke customisation capabilities.
The Congo project follows other successful work scopes on behalf of major oil and gas operators and contractors covering the North Sea, Mauritania, Norway and the Gulf of Thailand.
Decom Engineering Managing Director, Sean Conway, said, “Our latest project in deep water offshore Democratic Republic of Congo is another tick in the box for the versatility, safety and efficiency of our cutting technologies, adding to an extensive trace record of completed work scopes in the major hydrocarbon producing regions.
“Decommissioning redundant piping infrastructure or repurposing asserts to be converted for low or zero carbon energy storage is a massive global market, and we are committed to investing in research and development to ensure our clients have the most sustainable means at their disposal to address their needs.”
Razor Energy Corp. in conjunction with FutEra Power Corp. has announced the successful construction, commission and operation of its co-produced geothermal power project in Swan Hills, Alberta.
The project combines an Organic Rankine Cycle (ORC) Turbine, which captures geothermal heat from the production fluid, and a Natural Gas Turbine (NGT). Both the ORC and NGT have grid interconnections which enable direct sales of electricity to the Alberta grid, and both systems have been running in a steady state while optimisation efforts are being made in order to reach the designed capacity.
Razor produces and injects large volumes of hot production fluid on a daily basis as part of its ongoing conventional oil and gas operations, and FutEra capitalises on that by capturing the geothermal heat energy from the fluid and using it to generate power with zero greenhouse gas emissions. The co-production element of the project means there is no new surface land footprint as the project utilises existing assets such as processing infrastructure, producing wells, produced water reinjection system and an operating gathering and distribution system.
In addition, the co-production approach enables Alberta’s fledgling geothermal industry to develop alongside the powerhouse of Alberta’s world-class oil and gas operations.
Justin Reimer, CEO of Emissions Reduction Alberta, said, “Alberta has long championed the geothermal industry. It is exciting to watch an idea for a pilot project grow into an industry-scale, commercial operation. This made-in-Alberta solution ushers in a new era of clean energy that will spur an entirely new industry in the province that taps into our existing oil and gas resources and expertise.”
FutEra’s next phase of the project will see the addition of solar, and potentially carbon capture, with the objective to create a net negative carbon emitting traditional oil and gas asset.
Halliburton Company has introduced the RockJet family of reservoir-optimised shaped charges for the optimisation of downhole performance.
The RockJet family of charges was developed at the Advanced Perforating Flow Laboratory at the Halliburton Jet Research Centre using real rock under downhole conditions, and are the first charges to be certified using the American Petroleum Institute’s new perforation witnessed test protocol.
The charges allow for operators to enhance well productivity by providing optimum reservoir connectivity through deeper formation penetration and a larger perforation tunnel diameter downhole. They help increase production and improve well productivity by improving reservoir contact through deep and clean tunnels which extend beyond the damage zone.
When tested at downhole conditions, the RockJet charges delivered 22% higher penetration and an 83% increase in area open to flow.
Chris Tevis, Vice President of Wireline and Perforating services, Halliburton, said, “The RockJet family demonstrates our commitment to develop innovative technologies that drive increased production for our customers. In the perforating business, optimising penetration depth and flow area is the key.
“A lot of companies may have charges that are tested on the surface, but how they perform in downhole conditions is difficult to prove. By following the API’s new test protocol, we can provide our customers with confidence that the RockJet charges, custom engineered at JRC’s Advanced Perforating Flow Lab, will perform downhole.”
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