Well,he is the only bright spot, in this darkness, of days…zGood to see you, here,aallff
http://www.youtube.com/watch?v=D4160D7FAVE this cracks me up
[QUOTE=New Orleans Lady;39312]Question,was the first rig , which was deserted, a few weeks or monthes prior, near, or in the same drilling Hole <sorry,dont kknow what else to call it>? with regard the horizon?[/QUOTE]
It was on the same Macondo well (or hole) as the DWH. That first rig (the Marianas) had only drilled to 4,023 feet before getting battered by a hurricane and had to stop operations.
The DWH came back later to carry on the well.
A bit of background info here may help… http://en.wikipedia.org/wiki/Macondo_Prospect
Alf , interesting to note, that ya ll came to the same conclusion, as far as gas being mixed with the cement< pardon my verbage>. So , my question is,did the times get this info from this thread???
A bit of info/explanation on how the relief well is likely to take shape.
of course ya ll added that , bp changed the well design,was a variable…I wonder what cm1 is doing with all this info?
[QUOTE=New Orleans Lady;39308]crash dummy…please explain what the "majeure clause " means’ for us little rig people ?[/QUOTE]
“force majeure” is an escape hatch clause in a contract. Let’s say I had a contract with you to do your yard work in New Orleans, and you would pay me $50/week. Then Katrina hit, and the levees broke. The force majeure, Act of God clause would kick in, and both sides of the contract would be unenforceable for a considerable period. In context here, the operators are saying their contracts are off because of the moratorium, regulatory uncertainty etc… More here: http://www.library.yale.edu/~llicense/forcegen.shtml
[QUOTE=dell;39326]“force majeure” is an escape hatch clause in a contract. Let’s say I had a contract with you to do your yard work in New Orleans, and you would pay me $50/week. Then Katrina hit, and the levees broke. The force majeure, Act of God clause would kick in, and both sides of the contract would be unenforceable for a considerable period. In context here, the operators are saying their contracts are off because of the moratorium, regulatory uncertainty etc… More here: http://www.library.yale.edu/~llicense/forcegen.shtml[/QUOTE]
Merci’ beaucoup…<smile>
[QUOTE=New Orleans Lady;39323]Alf , interesting to note, that ya ll came to the same conclusion, as far as gas being mixed with the cement< pardon my verbage>. So , my question is,did the times get this info from this thread???[/QUOTE]
Nola can you point-me-to/give-me-a-link-to the “times” thread, so I can understand better what it is you are asking?
[QUOTE=Alf;39328]Nola can you point-me-to/give-me-a-link-to the “times” thread, so I can understand better what it is you are asking?[/QUOTE]
wall street journal,not times,http://rigzone.com/news/article.asp?a_id=93841
Our Last vacation,to Destin '09,Let us pray for our Land. http://picasaweb.google.com/lh/photo/K9EeNypWd9DNZMLJuGON8SQKboZDaGRfjQEHeG-s4Tg?feat=directlinkhttp://picasaweb.google.com/lh/photo/2MZ8Y9UwviOOeDi5_G2XRUbfKMOmugStn7WPsNsA934?feat=directlink
FYI, the Ocean Voyager is a semi.
[QUOTE=Crash Dummy;39298]Heard that the O Confidence semi is heading to Brazil O Endeavor semi is heading to Egypt and O Voyager jack-up is cold stacked. One of the other Diamond semi’s is headed to Africa i think.
Devon Energy declared the force majeure clause on Ocean Endeavor a semisubmersible rig, owned by Diamond Offshore. (West Cameron Block 184)
Murphy Oil declared the force majeure clause on Ocean Confidence a semisubmersible rig owned by Diamond Offshore. (Grand Isle Block 92)
Chevron declared the force majeure clause on Ocean Columbia a jack-up rig owned by Diamond Offshore. (South Timbalier block 134)
Arena declared the force majeure clause on Ocean Scepter a jack-up rig owned by Diamond Offshore. (South Timbalier block 134)
Cobalt declared the force majeure clause on Ocean Monarch a semisubmersible owned by Diamond Offshore.
Statoil declared the force majeure clause on Discoverer Americas a semisubmersible rig owned by Transocean. (Mississippi Canyon Block 540)
Statoil declared the force majeure clause on Maersk Developer a semisubmersible rig owned by Transocean. (Walker Ridge block 543)
Anadarko declared the force majeure clause on Noble Amus Runner a semisubmersible rig owned by Noble
Chevron declared the force majeure clause on Hercules 120 a jackup rig owned by Hercules Offshore. (South Timbalier 24[/QUOTE]
[QUOTE=alvis;39235]They are great pics indeed![/QUOTE]
The original hi-res images are at: http://www.bp.com/genericarticle.do?categoryId=9033571&contentId=7061902
JMac
This will be a long term liability for BP…
[QUOTE=bigmoose;39234]Sorry Alvis, I don’t know where larger source photo’s are. Hopefully scurvydog may return, I think he would be the best lead, as he was the original poster, I believe. Great pix, aren’t they!
clip All the best, Moose.[/QUOTE]
My apolologies for not including a link. They were so public on the BP site I thought everyone would have seen them already. Certainly caught my eye, particularly the test jig with two sheared pipes in it.
These images of the sheared long end of the risermay be of interest to some. One of the ROV’s got caught on it recently, I hadn’t seen it since they sheared it off.
And thanks to all here, I have read around 200 pages and found it very illuminating & heartwarming.
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Can someone please offer any viable explanations for 2 pieces of drill pipe stuck in the BOP as evidenced by the pics of the sheared riser? I take it that is quite likely why the BOP couldn’t do it’s job. Could that have been attached to or part of the tool that was lost down hole weeks before, and then got pushed back up as part of the event?
Looks like they will cut off the wobbling cap tonight or tomorrow, and replace it with the new cap, which may take 3 or 4 days. That means 3-4 days of “30-60,000 barrels per day” into the gulf. Maybe the A-Whale can prove its worth.
From Thad Allen’s update today (7/9):
We then used the big, hydraulic shears which were a very imperfect cut but we did cut it. So it was cut at an angle and we had this jagged cut. We have several feet down and then it is bolted—the lower marine riser package—by six bolts that go through phalanges which are those circles around that are connected to the pipes. We are going to physically unbolt that stub of riser pipe after we remove the containment cap. There are six bolts. They will be removed through the use of some tools, with ROVs.
We are even prepared to actually put in what we call a splitter that will actually force those two flanges apart if they become mated too closely because of the seawater and everything else. At that point we will completely remove that cut off stub of riser pipe and just deal with what we got. What you’ll have then is an open pipe with a phalange [I]and two pieces of pipe sticking up—the drill pipe and the piece of pipe that presumably fell down beside it as a result of the explosion and the riser pipe being bent over.[/I]
At that point there will be a metal strap put around both of those pipes to make them closer together so it’s easier to put something over the top of them. At that point, they’re going to put a cylindrical device over the top of the two pipes that are banded together. They’re within a larger tool, what they call a spool that will go down and fit over the phalange and be bolted back together. That piece will then become the connector and once we will put a manifold or a valve system on top that will allow us to basically shut in the well.
This will take place over a series of several days because we are doing all of this with remotely operated vehicles. All this equipment will be staged and hung off of the vessels that are in the area that will come in and then put the equipment in place and ROVs will be used to actually do the bolting…[FONT=Times New Roman]And to give you an idea of what we’re trying to do here—we estimate the pressure down in the reservoir – the pressure of the hydrocarbons coming up to be about 12,000 PSI or pounds per square inch. If you go to the top of a shut in—the device at the top—given the weight of all that oil and the well bore, the pressure up there should be less. Which we estimate should be around 9,000 PSI. So, once we get that well shut in and we take pressure readings if they are around 9,000 PSI that tells us something. That tells us that that entire column of hydrocarbons is being supported in the well bore.
[I]If it is something less than 9,000 then we have to explain why the pressure is less and where the hydrocarbons are going. That brings into play a discussion of the integrity of the wellbore which we talked about before[/I]. That all is going to be important information for how we are going to attempt to kill the well from the bottom. …[COLOR=#000000][FONT=Times New Roman]I think that entire process once we start unbolting until we’re in a position to put the new cap on, could be three to four days.[/FONT][/FONT][/COLOR]
[FONT=Times New Roman][COLOR=#000000][FONT=Times New Roman]
[COLOR=#000000][FONT=Times New Roman]Q: Hi Admiral, there’s been a number of scientist that have wanted to do some various type of testing on the flow rate to get a better idea of flow rate when the cap is taken off. I wanted to know—are they any plans to do any kind of a dye test or anything of that nature when this cap is being taken off? Why or why not?
ADMIRAL ALLEN: When we’re taking the cap off, the sequence of operations probably won’t allow for us to bring the other equipment that’s down there. My hope is that that will be required because once the cap is on, and we’ve completely sealed the wellhead, we will have empirical pressure data that will accurately tell us for the first time what the flow is.
And will be based on pressure of a closed system, rather than on the estimates that produce a range based on the high resolution video or the flow meter or the acoustic types of device we’ve been using trying to measure the density of the flow going forward and the velocity.
So I would think that once we have the new capping device on, we should be able to get probably the most accurate flow rate to date. It will be based on the actual pressure of the well.
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[QUOTE=champagne;39358]Looks like they will cut off the wobbling cap tonight or tomorrow, and replace it with the new cap, which may take 3 or 4 days. That means 3-4 days of “30-60,000 barrels per day” into the gulf. Maybe the A-Whale can prove its worth.
From Thad Allen’s update today (7/9):
[FONT=Times New Roman]. If you go to the top of a shut in—the device at the top—given the weight of all that oil and the well bore, the pressure up there should be less. [B][I]Which we estimate should be around 9,000 PSI. So, once we get that well shut in and we take pressure readings if they are around 9,000 PSI that tells us something. That tells us that that entire column of hydrocarbons is being supported in the well bore[/I][/B].
[B][I]If it is something less than 9,000 then we have to explain why the pressure is less and where the hydrocarbons are going. That brings into play a discussion of the integrity of the wellbore which we talked about before[/I].[/B] That all is going to be important information for how we are going to attempt to kill the well from the bottom. …[COLOR=#000000][FONT=Times New Roman]I think that entire process once we start unbolting until we’re in a position to put the new cap on, could be three to four days.[/FONT][/FONT][/COLOR]
[FONT=Times New Roman]
[COLOR=#000000][FONT=Times New Roman][COLOR=#000000][FONT=Times New Roman]Q: Hi Admiral, there’s been a number of scientist that have wanted to do some various type of testing on the flow rate to get a better idea of flow rate when the cap is taken off. I wanted to know—are they any plans to do any kind of a dye test or anything of that nature when this cap is being taken off? Why or why not?
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It should be an interesting couple of days…
Once they remove the cut riser adaptor flange they may be able to get a better idea where the flow is coming from ie either from the annulus, the drillpipe or both.
It will be interesting to see if they actually try and shut the well in with the mini-BOP…watch closely for erruptions from the seabed and around the 36" conductor when they start to close the BOP!!
Lots of people on this forum believe the well is flowing via the annulus (possibly from the casing as well). If the annulus pressure integrity has been compromised in any way (due to damage/split casing etc) then when they close-in, the oil flow will go elsewhere ie to the formation and seabed.
Also, there are rupture disks in the 16" liner (casing) which will definately rupture if they haven’t ruptured already!