North America

Valaris has secured new contracts and contract extensions to leave its associated contract backlog at approximately US$150mn.

The new scope includes:

• A two-well contract with Anadarko Petroleum Corporation in the U.S. Gulf of Mexico for semisubmersible VALARIS DPS-5. The contract is expected to commence in July 2023 and has a minimum duration of 60 days.

• A nine-well contract for a plug and abandonment campaign with Apache in the U.S. Gulf of Mexico for semisubmersible VALARIS DPS-5. The contract is expected to commence in September 2023 and has a minimum duration of 110 days.

• A minimum duration 180-day contract with an undisclosed operator offshore Australia for heavy duty modern jackup VALARIS 107. The contract is expected to commence in first quarter 2024.

• A one-year contract with an undisclosed operator offshore Australia for heavy duty modern jackup VALARIS 107. The contract is expected to commence in October 2024.

• A two-well contract with a major Australian operator for heavy duty ultra-harsh environment jackup VALARIS 247. The contract is expected to commence in early to mid-2024 and has an estimated duration of 100 days.

Expro has secured a contract with a major operator for the first deployment of its unique single shear and seal high-debris 15K ball valve assembly.

The multi-functional single shear and seal mechanism will form part of a full subsea deepwater completion/intervention system being designed by Expro for a long-standing and valued customer for a deepwater subsea field at about 6,600 ft in the Gulf of Mexico.

The mechanism is designed to answer the customer’s requirement for a versatile, single-valve subsea solution rather than the conventional double-valve system while offering the reassurance of risk reduction through an additional safety barrier.

Graham Cheyne, Expro’s Vice President of Subsea Well Access, commented, “We are proud to offer our innovative shear and seal solution to meet the needs of this important customer in the Gulf of Mexico. Our cutting-edge technology propels the industry’s momentum towards increased automation, improving safety on the rig floor by minimising personnel and mitigating human error, while providing an additional safety barrier. It offers operators with flexibility for their operations in both in-riser and open water subsea applications.”

Expro’s high-debris single ball system, which delivers shear and post shear seal on a multitude of sizes of coiled tubing, slickline, and electrical cable, is a solution for both gas and liquid. Its versatility makes it suitable for deployment in both in-riser or open water environments.

It is NACE MR0175 compliant and qualified for sour hydrogen sulfide environments. Bi-directional sealing is available even after a pump-through. The mechanism has been qualified to API 17G standard for the performance and design of subsea well intervention equipment. Its ability to handle up to 15% debris is a significant improvement over alternative mechanisms used in this environment today.

Expro’s shear and seal valve is available in the ELSA-HP 15ksi enhanced landing string assembly. It can be configured as a single valve, a single valve with a latch mechanism, or as a conventional subsea test tree arrangement, enabling flexibility. Expro is currently integrating the shear and seal ball system into its ELSA-HD 10ksi equipment and open water offerings.

The Bureau of Ocean Energy Management (BOEM) has proposed changes to modernise financial assurance requirements for the offshore oil and gas industry, in order to better protect American taxpayers from incurring the costs associated with the oil and gas industry’s responsibility to decommission offshore wells and infrastructure.

BOEM Director, Liz Klein, commented, “These proposed updates to our financial assurance regulations will help ensure that energy companies that are operating in publicly-owned federal waters are able to fulfill their clean-up and decommissioning responsibilities, without taxpayers having to step in to foot the bill. The commonsense updates that we are proposing would modernise evaluation and financial criteria so that we are better protecting taxpayers from the decommissioning costs associated with aging oil and gas infrastructure on the Outer Continental Shelf.”

Together with reforms to royalty rates, rental rates, onshore bonding requirements, and leasing practices, the changes being announced today continue to advance the Biden-Harris Administration’s federal oil and gas reform agenda, which was outlined in a report that the Department of the Interior developed in response to Executive Order 14008.

The proposed rule would establish two metrics by which BOEM would assess the risk any company poses for the American taxpayer.

To accurately and consistently predict financial distress, BOEM would use credit ratings from a nationally recognized statistical rating organisation, or a proxy credit rating generated through a statistical model. BOEM would require companies without an investment-grade credit rating to provide additional financial assurance. BOEM is seeking public feedback on whether it should rely on credit ratings to make these determinations and what credit rating threshold would best protect taxpayer interests without imposing undue burdens on industry.

Second, BOEM would consider the current value of the proved oil and gas resources on the lease itself when determining the overall financial risk of decommissioning, given that any lease with significant reserves still available would likely be acquired by another operator that would then assume the liabilities in the event of bankruptcy.

The proposed regulatory changes would provide additional clarity and reinforce that current grant holders and lessees bear the cost of ensuring compliance with lease obligations, rather than relying on prior owners to cover those costs.

BOEM would use decommissioning estimates based on industry reported data collected by the Bureau of Safety and Environmental Enforcement (BSEE) at a level that would adequately cover estimated decommissioning costs without being overly burdensome. This proposed rule would allow current lessees and grant holders to request phased-in payments over three years for new financial assurance amounts.

The proposed changes were published in the Federal Register on 29 June, which will open a 60-day public comment period.

The Bureau of Safety and Environmental Enforcement (BSEE) Director, Kevin Sligh, has announced a US$3mn investment from the Bipartisan Infrastructure Law to help reduce the risk of pollution from orphaned infrastructure on the federal Outer Continental Shelf.

The funding will specifically support BSEE decommissioning service contracts in the Matagorda Island lease area in the Gulf of Mexico. The funds are part of a nearly US$64mn commitment from President Biden’s Investing in America agenda to address orphaned oil and gas wells on public lands.

“The funding announced today under the President’s Bipartisan Infrastructure Law is critical for helping BSEE leverage available funds to tackle the backlog of decommissioning orphaned infrastructure offshore in the Gulf of Mexico,” commented Sligh. “If not properly decommissioned, offshore oil and gas infrastructure can become safety hazards, cause environmental harm, or interfere with navigation, fishing, or other uses of the Outer Continental Shelf.”

BSEE plans to award contracts to address nine orphan wells and associated pipelines and platforms in the Matagorda Island lease area, approximately 12 miles off the Texas coast. The initial contract will address the most immediate and urgent needs to reduce the risk of safety incidents and pollution in preparation for well-plugging operations.

An important part of BSEE’s responsibilities is to ensure that infrastructure used in exploration, development, and production activities undertaken according to the Outer Continental Shelf Lands Act is properly decommissioned to provide the long-term protection of the resource and the surrounding environment.

Petrofac, a leading provider of services to the global energy industry, has added a third Gulf of Mexico field, and extended the scope of its existing contract to decommission two fields, in the Gulf of Mexico.

Following this contract expansion, the legacy offshore fields and assets now include 12 platforms, 211 wells and 32 pipeline segments, as well as operations and logistics services. The scope includes the safe, efficient, and assured decommissioning of the fields and operation of the fields during the execution of the decommissioning work.

Petrofac will use its proven decommissioning programme management systems, tools, and processes to deliver the project. Its integrated local team, wider global decommissioning organisation and supply chain partners, have collectively plugged and abandoned more than 2,300 wells and decommissioned over 250 facilities.

Nick Shorten, Chief Operating Officer for Petrofac’s Asset Solutions business, remarked, “This sizable contract expansion recognises our industry-leading decommissioning programme management experience and our differentiated in-house capability to manage all well and asset decommissioning phases.

“Through this and other decommissioning projects, Petrofac is actively and sustainably contributing to the energy transition globally.”

Helix Alliance, the Louisiana-based subsidiary of Helix Energy Solutions Group, has been awarded a 39-well decommissioning contract for the Gulf of Mexico shelf.

Owen Kratz, Helix’s President and Chief Executive Office, said, “This award demonstrates Helix’s position as the preeminent company for full-field decommissioning in the Gulf of Mexico shelf, along with our other services supporting the full life cycle of offshore fields, following the expansion of our industry-leading decommissioning services with our acquisition of Alliance last year.”

The scope of work includes the plug and abandonment of 39 wells, 15 pipelines and seven structures. Helix Alliance plans to utilise the EPIC Hedron heavy lift derrick barge for structure removals, lifeboats for P&A activities, the Triton Explorer dive support vessel for pipeline abandonments and multiple Helix Alliance OSVs throughout the campaign.

C-Innovation (C-I), an affiliate of Edison Chouest Offshore (ECO) and its family of companies, has announced the completion of its 46th well intervention in the Gulf of Mexico.

C-I, a leader in providing turnkey intervention services for the global subsea industry, also successfully completed three new riserless zone perforations, an industry first in both deepwater and high-pressure operations. The well intervention programme provides increased efficiency along with faster response times for emergent situations through the quick mobilisation and deployment of a vessel. C-I specialises in downhole operations, including production injection and integrity logging, caliper measurements, and setting water shut-off and zone bypass plugs. With more well intervention operations planned for 2023, C-I has played a pivotal role in increasing output for operators in the Gulf of Mexico.

George Wilson, Riserless Light Well Intervention Project Manager, C-I, said, “We are very proud to be a part of increasing oil production in this challenging geo-political climate. Riserless interventions on vessels offer both time and cost advantages over riser interventions. C-I’s programme offers the added benefit of dedicated dock space with advanced fluid tracking for faster between-well maintenance.”

C-I’s well intervention programme, which made its debut in 2017, has performed 31 hydraulic interventions and 15 mechanical interventions. The mechanical interventions included a total of 85 successful wireline runs, both e-line and slickline. C-I recently completed its longest mechanical intervention on board the vessel, Island Venture. With 79 days offshore, the operation included 22 e-line and slickline runs, as well as 22,205 barrels of fluid pumped into the well.

Wilson added, “C-I is a fully integrated service provider for our clients. Our turnkey solutions for well interventions alleviate the hassle of coordinating and managing the multitude of subcontractors needed to address complex jobs."

Researchers at the University of California, Davis, have suggested the cost of permanently plugging and abandoning the inactive oil and gas wells across the waters near Alabama, Louisiana and Texas could be upwards of US$30bn.

A paper released in the Nature Energy journal stated the area is home to 14,000 inactive wells that have not produced for five years and are unlikely to be reactivated in the region that has become the epicentre of US offshore oil and gas operations.

Leaks from wells closer to shore are more likely to damage ecosystems and release GHG emissions compared to deepwater wells. Studies have found that more than 90% of inactive wells are in shallow waters, and the costs to perform P&A services on those alone would be US$7.6bn.

The findings could help states makes decisions regarding their clean-up priorities, especially as US$4.7bn in federal funding has been authorised by the Infrastructure Investment and Jobs Act.

Liability falls to prior owners to plug and abandon wells in federal waters if the current owners become insolvent and are unable to cover costs. Large US oil companies currently own or have previously owned 88% of the wells in federal Gulf of Mexico waters and would legally shoulder the P&A liabilities.

However, in individual state waters, each jurisdiction handles liability differently, and prior ownership isn’t relevant. States oversee plugging programmes for orphaned wells whose owners have claimed bankruptcy.

“The bulk of the cost comes from plugging wells in deeper water where the environmental consequences are less than for shallow wells closer to shore,” said Mark Agerton, an Assistant Professor at UC Davis and lead author of the paper published.

“That money is probably better spent on state waters where they can’t go after prior owners for clean-up costs and it’s going to be a cheaper clean-up job with more environmental benefit.”