A GoM operator witnessed a leaking 6” pipeline. Upon repairing the visual leak and attempting to perform a successful hydrostatic pressure test a second non-visual leak occurred, ultimately resulting in extended production loss.

In order to perform a second assessment and bring production back online, the pipeline assessment required a 100% fluidpacked volume of seawater to ensure an oxygen-free environment.

Developed an integrate-able tool to accurately calculate the leak rate of SCSSV which considers the existence of liquid and gas in the wellbore, wellbore cooldown and USV leak during the routine SCSSV test.

Developed and supported the integration of the flowline virtual metering system utilizing the GATE Prho™ engine.

A Louisiana operator experienced integrity issues with an existing 3 inch saltwater disposal pipeline. Production history recorded multiple leaks in the existing pipe, which resulted in environmental remediation. Upon investigation the operator determined that the said discharge pipe was unsuitable for future use. BlueFin was sought to review the situation and develop a plan of action that would resolve the integrity issues.

GATE was engaged to evaluate the current condition and remaining life of the subsea jumpers and flowline of a deepwater oil and gas facility in the Gulf of Mexico.

The subsea field, which was comprised of multiple oil wells, was produced at a Tension Leg Platform (TLP) with a nominal capacity to produce 100,000 barrels of oil and 50 million cubic feet of gas per day. The subsea and topsides facilities were designed to operate with an expected maximum carbon dioxide (CO2) concentration of 0.15 mole percent from any given producing well.

After an in-line inspection of a pipeline in West Africa, a client discovered significant wall loss in the first three miles of the line. The tool also returned significant wax deposits, casting doubt on the current wax management efforts in place.

The wells producing to the pipeline historically produced H2S; however, the worst offenders were shut-in quickly after it was discovered that they were producing extremely high concentrations of the sour gas.

The review of the remaining cathodic protection (CP) life of a Gulf of Mexico tension-leg platform (TLP) was undertaken to evaluate the ability of the current systems to support a 20-year life extension. At the same time, the opportunity to include non-destructive riser testing into the life extension program was also identified.

Developed standalone tool for operator to proactively monitor flow assurance risks based on the field specific reservoir fluids, subsea infrastructure and current operating conditions.

A large and complex offshore field in the Middle East was suffering from multiple leaks due to corrosion in the presence of high levels of CO2 and H2S in the production, seawater injection, aquifer water injection and produced water injection systems. This was resulting in excessive chemical injection expenditures and was impacting field revenues and uptime. The large, shallow water field consisted of several hundred wells and a complex hub and spoke infrastructure.

Provided complete hydrate blockage remediation support from initial onshore Engineering Assessment to execution planning and eventual successful field execution using nitrogen.

A Gulf of Mexico (GoM) operator in the process of decommissioning one of its fields requested the engineering assessment of a blockage existing in their flowline-riser. The reservoir fluid characteristics and the field’s operational history were extensively reviewed. The review indicated hydrates to be the likely cause of the blockage.

Custom solvent products and flow assurance engineering provide total approach to plugged GoM pipeline.

LiquiGel® pig maps internal pipeline geography and provides target area for remediation pill with no shut-in required.

A West Africa field operator witnessed an abnormal increase in pressure topsides when the flowline circulation pump was used to pump dead oil into the production line. No increase in subsea pressure was observed. Operational history prior to blockage hinted at the possibility of the presence of one or both wax and hydrate blockages in the production line. Depressurization options were limited by the blocked gas lift line.