Monthly Archives: May 2011
I checked into the emergency for testing and treating. I have kept up with reading most posts, but is hard to remain awake. Like now I am getting sleepy again and the pain is a 10 out of a 10.
By Trent Jacobs, Helix Energy Solutions
Currently there are more than 5,000 subsea wells scattered across the globe, with more being drilled every day. Many of those wells are already a decade old with many more not far behind. That’s why in the last several years the techniques offered through well intervention have become ever more necessary to keep up with rising global demand for oil and gas.
Well intervention holds the potential to extend the productive life of aging wells and repair damaged or underperforming wells. Well intervention can bring oil and gas companies substantially higher profits off otherwise non-economical wells. Helix ESG’s well intervention unit, Helix Well Ops, is the global leader in this specialized arena of offshore work and boasts some of the most advanced assets the industry has to offer.
But what exactly is well intervention?
Generally speaking, well intervention is any process that enhances the quality of the subsea well, provides data to help manage the production rate of the well or shuts off and safely abandons a flowing well.
One of the biggest challenges in subsea well intervention is keeping costs down. So rigorous and extensive preplanning is used to identify the best potential solutions while mitigating a multitude of known and unknown risks.
After assessing a particular well’s condition and selecting a proper treatment, which could involve a number of different procedures and contingency plans, a specific type of vessel is then selected to carry out the task. Most operations can be carried out using light and medium intervention vessels equipped with dynamic positioning like Helix ESG’s monohull vessels the Seawell and the Well Enhancer, but for heavy intervention work, like redrilling an under-producing well, an offshore drilling unit is needed.
Among all the various types of well intervention operations, through tubing is the most commonly applied. Through-tubing enables recompletion, stimulation or repair work to be done inside a flowing oil or gas production line for the entire length of the well.
This procedure is used to complete many different tasks including the removal of obstructions inside the well that may be blocking the flow of hydrocarbons, simply evaluating the well’s condition, stimulating the well chemically or repairing a damaged well casing. Each job requires a specific type of tool that can be delivered down inside the well itself and in light intervention procedures the systems used include coiled tubing, electric line (e-line), slickline and braided wireline.
Slickline is an unbraided wire used to deliver a wide array of specialized tools down into the well for maintenance and data collection. E-lines provide more flexibility for mechanical and electrical operations and can also send back real time logging data which means engineers don’t have to wait for the tool to be pulled back out of the well to learn of its condition.
E-lines can include the use of a braided line which is more complex than slickline and requires a special grease injection system to ensure there is enough pressure for the blowout preventer to seal around the wire as it goes down into the well.
Braided lines are stronger that slicklines and can be used to perforate wellbores with explosive charges or fish out logging and monitoring tools placed deep inside the well. Both slickline and e-line jobs can be completed without the use of a rigid riser that connects the subsea well head to a vessel floating on the surface.
Coiled tubing is by far the most effective and versatile tool for well intervention. Coiled tubing is a continuous string of tubing that can be rolled onto a spool and is used is often used to pump chemicals or gasses directly into the well to relieve blockage and increase flow. But coiled tubing is used for a wide variety of other tasks such as drilling, logging, cleaning, cementing,” fishing” out tools and well completion and production. In many cases coiled tubing requires a riser or a subsea tool known as an injector head that is placed on top of the well and can cut through the coil to shut off the flow of oil or gas if an unexpected problem arises. To perform these types of operations offshore,
Well Ops has a world class fleet of three purpose built vessels and an arsenal of heavy well intervention equipment that can be mobilized for work in all of the world’s major offshore oil and gas fields.
The mono-hull Seawell pioneered the light well intervention market with its inception over 20 years ago and continues to provide riser-less well intervention solutions in the North Sea. The Seawell is capable of conducting wireline and e-line operations and utilizes its diving capabilities for wells that can only be accessed by divers.
The cutting-edge Well Enhancer, launched in 2009 and also based in the North Sea, provides open water and riser based intervention services supported by diving and ROV capabilities.
Well Ops flagship, the Q4000, is one of the world’s most unique multi-service vessels and entered into service in the Gulf of Mexico in 2002. As a highly cost-effective alternative to using a drilling rig, the Q4000 is capable of virtually every type of well intervention operation, including subsea oil spill containment, and is can work in water depths beyond 10,000 feet.
- Interwell raises the bar in well intervention technology (mb50.wordpress.com)
- STX Finland Inks Contract with Eide Marine Services for Two Well Intervention Vessels (mb50.wordpress.com)
- Sarah: deepwater intervention vessel (mb50.wordpress.com)
Distrigas of Massachusetts LLC, a subsidiary of GDF SUEZ Energy North America, announced that it is providing LNG (liquefied natural gas) to the first LNG refueling station east of the Mississippi River.
Enviro Express Natural Gas, LLC owns and operates the combination LNG and CNG (compressed natural gas) refueling station in Bridgeport, Connecticut, adjacent to Interstate 95. This represents the first time LNG has been sold as a vehicle fuel from Distrigas’s Everett Marine Terminal.
“Interest in LNG to power fleet vehicles is increasing significantly as diesel fuel and gasoline prices continue to climb,” said Joe Murphy, vice president, Sales and Transportation for Distrigas. “The difference in fuel and maintenance costs and the environmental benefits make LNG an attractive vehicle fuel alternative.”
The public-access refueling station presently provides LNG to Enviro Express’ new commercial fleet of 18 Kenworth T800 semi tractor-trailers and CNG to fleet customers. Enviro Express is a waste collection and transport company, which uses its fleet to haul ash and other refuse from Bridgeport to Putnam, Connecticut, a 110-mile trip.
Partially funded by the American Recovery and Reinvestment Act of 2009, the $6.2 million project is part of the larger Connecticut Clean Cities Future Fuels project.
By switching to LNG, Enviro Express’ fleet is able to displace approximately 500,000 gallons of diesel fuel annually and remove hundreds of tons of particulate emissions from the air. The switch to a cleaner fuel should also lower vehicle maintenance costs and allow the trucks to travel farther between oil changes. Additional savings is realized because the price of LNG is much lower than the price of diesel fuel and gasoline.
Adding to the environmental benefit, the fueling station is a closed system which recaptures boil-off from the LNG that would otherwise vent into the atmosphere and compresses it to be stored as CNG.
“LNG is lighter than diesel, so we can go farther, cleaner, and improve load efficiency by hauling more with the same vehicle,” said Bill Malone, of Enviro Express.
By OGJ editors
HOUSTON, May 10 — DCP Midstream LLC, Denver, and Targa Resources Partners LP, Houston, have reached agreements that will, according to the joint announcement, provide a “long-term anchor commitment” to DCP Midstream’s Sandhills Pipeline and an interconnect of the pipeline to a new delivery point with Targa’s Cedar Bayou fractionators’ plant at Mont Belvieu, Tex.
DCP is negotiating with several customers, it said, to sign long-term commitments to the Sandhills Pipeline.
Additionally, DCP and Targa reached a long-term anchor commitment by DCP for a new 100,000-b/d fractionation expansion at the Mont Belvieu plant, which Targa operates and of which it is majority owner.
In November 2010, DCP Midstream began an open season and is currently securing right-of-way and environmental permits for the Sandhills Pipeline. The new 700-mile system will move Y-grade NGLs from gas plants in the Permian basin and South Texas to various fractionators along the Gulf Coast along with the Mont Belvieu NGL hub.
The Sandhills Pipeline will serve NGL transportation needs at Targa’s gas plants, existing DCP gas plants, and the 200-MMcfd DCP Eagle plant designed to serve Eagle Ford shale gas development. The Sandhills pipeline and CBF target first-half 2013 for completion of construction and start up.
Significantly, the Sandhills Pipeline along with CBF’s new fractionation expansion will allow DCP to handle producers’ increased liquid-rich natural gas production from the new Avalon Shale-Bone Springs areas, said the announcement, as well as the Eagle Ford shale area.
Queensland’s recent heavy rains and floods could delay the expansion of BG Group’s $18 billion Queensland Curtis LNG plant at Gladstone because the British gas giant has been unable to shore up gas reserves as quickly as it had hoped.
Speaking to investors in London on Tuesday night, chief executive Frank Chapman said BG was still targeting a mid-2012 sanction of a third LNG production train at Gladstone.
“The name of the game at the moment is the maturation of that reserves and resources base within that period,” Mr Chapman said.
“That has suffered some impact because of the flooding and the impact that’s had on access to drilling sites, but we’re still focused on moving some of that prospective resource into a more, higher confidence level to underpin a third train.”
Despite the rains, BG was still on track for first LNG exports from Gladstone in 2014, he said.
BG was the first of three big CSG-to-LNG proponents planning exports out of Gladstone from 2014.
Mr Chapman joined the chorus of voices touting stronger LNG demand because of the Japanese earthquake and subsequent Fukushima nuclear disaster.
He said the flow-on effect was likely to be long-term. “After (the) Three Mile Island (1979 nuclear accident) in the US, we saw lead times for nuclear projects going out to something like 12 or 13 years, and associated with that will be increased costs associated with more stringent regulatory safety requirements,” he said.
“All of this, I think will result in medium to long-term higher gas demand for power, and as a consequence, extra demand for LNG, and this is going to cause a further tightening of a market situation which we already regarded as quite tight.”