Project Details

Client: ExxonMobil

Location: Julia Field

Overview

Open an FS2 valve using UHD ROV power only.

Challenges

Create a viable and economical procedure using an UHD ROV and related equipment that is compact and powerful enough to actuate the FS2 valve through existing tree communication ports.

Client Solution

• We designed, built and deployed a subsea tree controls interface system which leverages the existing infrastructure and technology of the ROV systems. The interface system utilized 100% subsea ROV-based tooling to actuate the well’s lower completion isolation valve.
• C-Innovation was contracted by ExxonMobil to open several wells. We successfully actuated four FS2 valves to the open position using this system. Exxon considers the procedure a monumental success and a long-term solution to an otherwise costly adventure.
• The process improved with each well activation. Since the procedure had never been done before, there were some early calculations that were purely speculative. Moving Forward, actuating the FS2 valve to create a fully functional tree can be done in under 3 hours.

Why were these services chosen?

The drilling and completion rig had already moved offsite and would have had a high cost and even higher impact to the remaining drilling and completion schedule to bring it back to do this job. We developed this solution to capitalize on and leverage existing infrastructure to provide a new ROV service to complete a task that is essential to production start-up.

Results

We have created another option for operators to start-up and commission their wells and fields which reduces the cost and allows for more flexibility in logistics. We used a novel but simplistic system to leverage our existing ROV technology to interface with a more advanced subsea tree (XT) control system.  Earlier generations of subsea control technology would require a more advanced interface kit for the ROV, but we have proven this is possible though other implementations of technology with cooperation from the client and subsea hardware providers. We are changing how the industry can respond to subsea equipment and well issues with existing technology and greater speed and still maintain reliability in control.

Estimated saving were $3M USD per well (when compared to accomplishing the same with a rig and riser)

The rig’s primary mission is drilling and completion, keeping it onsite to actuate this valve reduces the overall value of the rig deployment. With rig day rate and availability what they are, it is important for an operator to move the rig off the well center and to the next drilling location sooner. In this case, the rig had already moved offsite and would have needed to transit back (at its low rate of speed and high rate of cost) and redeploy a riser system to perform this simple task. Using a small vessel and ROVs, we enabled this to be done quicker without distracting the rig from its current path.

Client: Major O&G Operator

Project: Europa 136 W Flowline Remediation

Location: GOM – 3500’

Overview

The primary objective of this project was to clear the flowline of an extensive asphaltene blockage to satisfy government decommissioning requirements.

Challenges

• Accessibility to the flowline
  • Blockage was closer to the upstream/PLET end of the flowline
  • PLET is in almost 4,000ft of water
  • Decided to lift flowline to surface for surface injection of CT to reduce total distance to blockage
• The raised flowline would require…
  • Lifting/threading through the moonpool of the vessel
  • An adequate hang-off structure to support the catenary weight (plus safety factors).  A custom moonpool bridging system was designed & built by NAS for this portion of the solution
  • Change-out of interface once recovered to allow for CT injection
  • Additional structure to support rig-up of a BOP & injector system and allow for safe workspace around the equipment
• Full extent of blockage was unknown
• Flowline was to be flushed for cleanliness after blockage remediation which required service vessels at the TLP and the PLET
• Large quantities of solvent would be needed for the job
• Expected volume of returns from the flowline would required a large capacity of hazardous material storage and offloading to another vessel while on-site
• The downstream side of the flowline (on the TLP) required a temporary interface to the riser, and nitrogen packing & water flushing systems
  • The nitrogen packing was to provide positive indication of breakthrough on the solid blockage
  • The water pumping system was to flush the remediated flowline to regulatory cleanliness standards for decommissioning
  • There is only enough room on the platform for the temporary system which directly interfaced with the riser, all other systems were deployed on a PSV with a flexible hose connecting the systems on the TLP and the system on the PSV

Client Solution

• The flowline was safely recovered & secured, and the interface was changed for intervention
• The downstream (-of the blockage) end of the flowline was packed with nitrogen
• Asphalatenes blocking the flowline were removed (NOTE: not all were removed due to the extensive conditions.  The client decided to cease intervention after an approved period of time, and demobilize.  This was to no fault of CI, and our solution was still deemed a success…just applied to worse conditions than the client expected to encounter)
• The Island Venture was on charter to Shell for 26.16 days.  However, the preparation for this project began months in advance.
• C-Innovation Subsea Projects Group—project management, engineering, offshore management, logistics, client relations/interface
• ECO MSV Island Venture – primary intervention services
• ECO PSV (C-Captain) for platform services—i.e., nitrogen & water pumping
• ECO PSVs (Robin & Ms. Charlotte) for offloading & storage of returns
• C-Innovation UHD-311 and -312 for ROV support services
• NAS naval architecture design-build services
• Bollinger for sea-fastening implements
• Halliburton Coiled Tubing
• Halliburton BOP services
• Halliburton Pumping
• Halliburton for platform interface
• Halliburton Nitrogen Generation
• PTS separation systems
• Acute Welding Services for pipeline cuts & interface change-out

Why were these services chosen?

Skilled, integrated team that brought effective one-stop-shop solution to client

How is it unique/different from other similar company/industry-wide projects?

We lifted a pipeline off of the seabed, threaded it through the moonpool of vessel, and supported it for weeks while a surface intervention was performed.  This is unheard of.  The job was deemed impossible.  C-Innovation Subsea Projects & Team Venture was the only party brave enough to provide a viable solution for the client’s challenge.

Results

The client is sole-sourcing a phase 2 solution through us to complete the work scope.  More engineering, more planning, more services.  We’re going to get that pipeline off of the seabed for them safely and without impact to the environment.

We are solidifying our status as a serious, competent solution provide in the industry.

The client was so pleased with our performance that we are being offered opportunity to additional, diverse work from them—effectively winning share of a rather closed market.