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TechnipFMC has several long-term alliance partners, in- The project he’s referencing involves two ? elds combined under cluding Lundin, Neptune and Wintershall DEA. In its ? fth one iEPCI award: Solveig (formerly Luna II) and Rolvsnes, for iEPCI alliance partner, TechnipFMC’s existing partnership tieback to the Edvard Grieg platform in the Norwegian North Sea. with Wintershall was announced in July 2019 to be expanded The iEPCI contract follows on previous iFEED work and contin- to create additional value through integrated FEED, integrated ues on a long-term alliance agreement formed in 2017. For Lun-

EPCI and integrated life of ? eld services. din, the goal of the cooperation is to involve the supplier Technip-

The ? rm’s alliance agreement with Neptune has been FMC earlier on to accelerate and simplify project developments.

signed for an initial ? ve-year term with options for further ex- Selvig also pointed to advantages recognized through its tensions, and covers the full project lifecycle from early con- work with Equinor, speci? cally mentioning the Trestakk proj- cept work, through engineering, procurement, delivery of SPS ect, a Norwegian Sea tieback to the Åsgard A ? oating produc- and installation of subsea equipment and infrastructure, and tion vessel. continues into life of ? eld support (TechnipFMC also offers “When it comes to Equinor and the [integrated] projects we integrated life of ? eld services, or iLOF). have run with them, they see that there is low variation orders,

The ? rst projects to be executed under the alliance agree- so they save contingency on the project on their side. We are ment, Duva and Gjøa P1, are being developed under one iEP- able to deliver much quicker, and actually the Trestakk project

CI award, which TechnipFMC says is worth between $250 we delivered and installed on the seabed in 22 months – which million and $500 million, as fast-track subsea tiebacks to the has never been done before,” he said.

Neptune operated Gjøa facilities in the Norwegian North Sea. Trestakk, which consists of three production wells and two

TechnipFMC will supply the subsea equipment from the gas injection wells, had originally been seen as too expen- wellheads to the riser hang-off at Gjøa, including subsea tem- sive to develop, but simpli? cation and streamlining achieved plates, xmas trees, manifolds, production and gas lift pipe- thanks in part to iFEED and iEPCI helped to drive down costs. lines, umbilicals, subsea structures and control systems, plus Anders Opedal, Equinor executive vice president for tech- installation activities. The ? rst template is expected to be in- nology, projects and drilling, said in Equinor’s July statement stalled on the Duva ? eld during the second half of 2019 ahead announcing ? rst production from Trestakk that development of ? rst oil targeted for the ? rst half of 2020. costs nearly halved before the ? nal investment decision (FID)

The alliance agreement and Duva and Gjøa P1 call-off fol- was made, and then again even further from FID to start-up low on another Neptune integrated project currently under- thanks in part to TechnipFMC. way. In late 2017 VNG Norge – acquired by Neptune in June Under its iEPCI award, TechnipFMC supplied and installed 2018 – awarded TechnipFMC an iEPCI contract worth more the ? exible riser, production ? owline, gas injection line, than $250 million including trees, manifold, controls, riser ? exible jumpers, umbilicals and SPS with subsea trees and bases, the world’s longest electrically trace heated pipe-in- completion system, a manifold, wellheads, subsea and topside pipe (ETH-PiP), rigid ? owlines, ? exible risers, umbilical and control systems and tie-in hardware and tools. “We were able installation for Fenja (previously known as Pil & Bue), a long to bring down cost of our scope close to 20%,” Selvig said.

42-kiliometer tieback to the Equinor-operated Njord platform. Additionally, Equinor has stated during their lessons learned

The electrically trace heated technology will help to avoid seminars that they have had signi? cant savings on their side ? ow assurance issues for the ? owline, Selvig said. “We are in outside of its contract scope with TechnipFMC during execu- the midst of execution,” he said, with ? rst equipment deliver- tion and follow up, he said. ies ongoing and good progress being made within the technol- In addition to better time to ? rst oil and reduced cost on ogy quali? cation program. the seabed (including capex and install-ex), Selvig said risk

In addition, the company announced a new iEPCI award mitigation during the execution schedule rounds out the list of from Neptune Energy in late July. Under the terms of the “top three” bene? ts for iEPCI. TechnipFMC is able to handle contract, which TechnipFMC says is between $75 and $250 all of the interfaces between the SPS and SURF packages in- million, the company will manufacture, deliver and install ternally. According to Selvig, this offers bene? ts such as bet- subsea equipment including production and water wash pipe- ter planning control, no variation orders and adjusted terms lines, umbilicals, subsea structures and control systems for the and conditions in the contract that are in favor of the client

Seagull project in the Central North Sea. (the same warranty period for SPS and SURF, for example). “[iEPCI] is a clear trend that is increasing. If you look at larger “Lessons learned” contracts over the past three years, close to 40% have been iEP-

Commenting on the iEPCI work performed to date, Selvig CI globally, and for Norway it’s the same ? gure; we have been said, “There’s a couple of lessons learned from what we have awarded approximately half of these contracts,” Selvig said.

done. If you take the Lundin case where we are currently exe- “The interest for iEPCI continues to increase, so we should cuting, it was stated by the Lundin Norway CEO that because of expect that we will see an increasing percentage of the total this contract model they have saved at least one year to ? rst oil.” market being integrated,” Selvig said.

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