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Posted on 5/2/10 at 2:12 pm to COTiger
Sounds like he doesn't think they can get enough done before it's really bad. Or at least that's what I get from it.
Replied, no response.
Replied, no response.
Posted on 5/2/10 at 2:13 pm to QuietTiger
Thanks 
Posted on 5/2/10 at 2:13 pm to SCTiger
quote:
I thought cementing filled the annular between a casing and the borehole?
The annular is short for Annular blowout preventer. It does close off the annulus. (Space between the casing and outside of the drill string) If there is no drill pipe or tubing string across the annular preventer, it will close to seal the whole area. (Hole)
This post was edited on 5/2/10 at 2:18 pm
Posted on 5/2/10 at 2:40 pm to shaunk128
quote:
Only with the spill and the cleanup, not the accident. With the accident only time will tell
It's BPs responsibility to inform the drilling company of what type of reservoir pressures and gas charged zones they are going to be dealing with. If they underestimated what they were going to be dealing with inthe subsurface than thats on the operator.
Posted on 5/2/10 at 2:42 pm to lsugradman
quote:
It's BPs responsibility to inform the drilling company of what type of reservoir pressures and gas charged zones they are going to be dealing with. If they underestimated what they were going to be dealing with inthe subsurface than thats on the operator.
we are wildcat rigs. all we know is that there are hydrocarbons down there. we don't know anything else. and, neither do they. especially not pressure ratings.
Posted on 5/2/10 at 2:55 pm to tigerdup07
You are telling me that when a company decides to drill in a certain location they have no idea what zones and what sorts of pressures they are going to encounter there? And that they arent responsible for making sure the drilling co is aware of those issues and their equipment isnt rated appropriately?
This post was edited on 5/2/10 at 2:58 pm
Posted on 5/2/10 at 3:03 pm to tigerdup07
Here are some questions for the pros on here that come from bits and pieces picked up on other blogs/message boards.
one theory is that the BOP failed because a heavy piece of downhole equipment got stuck in the BOP and that thicker-than-pipe piece could not be pinched. what could be down there?
another theory is that the BOP failed because, when the superfast gas bubble started running out of the hole and into the riser, that it was carrying sand and/or cement that sand-blasted or eroded the "elastometers" on the BOP, thereby rendering a complete seal ineffective.
I believe that haliburton has stated that they had cemented the formation 20 hours prior to the explosion, but they had not yet set the cement plug to temporarily abandon the well.
there is a report that BP needed to remove some kind of expensive, synthetic mud in the riser for another job and that this mud was then exchanged for seawater. the guy on the radio interview did say that a workboat was on location offloading mud through a hose and that boat was later involved in rescue operations. is it customary to put seawater in the riser when there are still downhole operations to be conducted?
without any mud weight above the BOP, what precations are taken to bleed off gas at the BOP before the BOP is re-opened?
there has also been mention that the Horizon was going to move off location to its next job very soon and that a completion rig was ready and waiting to move on location. does that affect abandonment operations any?
could you give us the basic steps, in sequence, of what is needed to temporarily abandon a well?
BTW, thanks for your insight, guys.
one theory is that the BOP failed because a heavy piece of downhole equipment got stuck in the BOP and that thicker-than-pipe piece could not be pinched. what could be down there?
another theory is that the BOP failed because, when the superfast gas bubble started running out of the hole and into the riser, that it was carrying sand and/or cement that sand-blasted or eroded the "elastometers" on the BOP, thereby rendering a complete seal ineffective.
I believe that haliburton has stated that they had cemented the formation 20 hours prior to the explosion, but they had not yet set the cement plug to temporarily abandon the well.
there is a report that BP needed to remove some kind of expensive, synthetic mud in the riser for another job and that this mud was then exchanged for seawater. the guy on the radio interview did say that a workboat was on location offloading mud through a hose and that boat was later involved in rescue operations. is it customary to put seawater in the riser when there are still downhole operations to be conducted?
without any mud weight above the BOP, what precations are taken to bleed off gas at the BOP before the BOP is re-opened?
there has also been mention that the Horizon was going to move off location to its next job very soon and that a completion rig was ready and waiting to move on location. does that affect abandonment operations any?
could you give us the basic steps, in sequence, of what is needed to temporarily abandon a well?
BTW, thanks for your insight, guys.
This post was edited on 5/2/10 at 3:05 pm
Posted on 5/2/10 at 3:06 pm to COTiger
quote:
quote:
Also said we've opened Pandora's box and can't close it.
Elaborate please.
I think he means that the oil booms are not going to do any good because of the weather. The water is going to be very choppy causing the oil to jump the booms. Basically, wasting time putting them out there.
I could be wrong because I do not know jack about drilling. I also wanted to study it, but never did.
Posted on 5/2/10 at 3:24 pm to MSTiger33
quote:
You are telling me that when a company decides to drill in a certain location they have no idea what zones and what sorts of pressures they are going to encounter there?
I would say that they don't really know until they get there. They can have some educated guesses and prepare as best they can. But there is really no way to know.
Posted on 5/2/10 at 3:25 pm to gliterein
quote:
there is a report that BP needed to remove some kind of expensive, synthetic mud in the riser for another job and that this mud was then exchanged for seawater. the guy on the radio interview did say that a workboat was on location offloading mud through a hose and that boat was later involved in rescue operations. is it customary to put seawater in the riser when there are still downhole operations to be conducted?
without any mud weight above the BOP, what precations are taken to bleed off gas at the BOP before the BOP is re-opened?
Synthetic mud has to be reclaimed. It is expensive; but, I believe they are required by law to reclaim as much of it as they can.
Your last question seems to be the key to it all. Why didn't they see something below the Annulars before they opened them?
Posted on 5/2/10 at 3:27 pm to ItTakesAThief
Is there an article or any information that can give me the nuts and bolts of drilling? I know it is complicated, but I don't quite understand all the terminology and abbreviations.
TIA
TIA
Posted on 5/2/10 at 3:41 pm to lsugradman
quote:
It's BPs responsibility to inform the drilling company of what type of reservoir pressures and gas charged zones they are going to be dealing with. If they underestimated what they were going to be dealing with inthe subsurface than thats on the operator.
Isn't TO the operator? Did TO rent/buy the BOP from Cameron? Didnt Cameron build the BOP?
I dont see how any of that has to do with the pressures of the reservoir.
Posted on 5/2/10 at 3:55 pm to tgrbaitn08
BP is the operator. Its BPs responsibility to make sure that the worst possible scenario is considered for any given well and to make sure the drilling company is not only aware of it but the equipment used (including and especially the Cameron BOPs) can handle that scenario. Now they may have very well done that and the BOPs failed under a condition where they should not have. We dont know at this point. But trust me operators should have at least a high case estimate of the type of reservoir pressures that may be encountered for any type of well. And the reservoir pressures are extremely important bc that is where the kick typically originates.
Posted on 5/2/10 at 3:57 pm to tgrbaitn08
Ms tiger check out you tube
find glossary of jargon at
LINK
find glossary of jargon at
LINK
This post was edited on 5/2/10 at 4:07 pm
Posted on 5/2/10 at 4:08 pm to lsugradman
quote:
It's BPs responsibility to inform the drilling company of what type of reservoir pressures and gas charged zones they are going to be dealing with. If they underestimated what they were going to be dealing with inthe subsurface than thats on the operator.
I will assume that all you know about the oil and gas industry is that you can pull up to the gas pump and fill your vehicle with the gas that is processed with the oil that is brought to surface by the oil wells in the Gulf.
The Operator (BP) hires out Transocean to drill a well for them. They work very closely together in all decesion making and planning. They have BP reps on location as well as Transocean Reps. They have meetings several times a day with the folks in the office to discuss current operations and operations moving forward, as well as any unplanned events. They were well aware of the downhole pressures. Everyone was, that is the only way they could have drilled it. They used proper mud weights to offset the reservoir pressures to drill the well safetly. You make it sound like BP hires Transocean and tells them. "Hey I want a well drilled at this location, go drill it and let me know when you are done"
Posted on 5/2/10 at 4:16 pm to gliterein
quote:
one theory is that the BOP failed because a heavy piece of downhole equipment got stuck in the BOP and that thicker-than-pipe piece could not be pinched. what could be down there?
It is possible that some heavy wall pipe was across the bops and the bops could not cut it. Many other things are posible as well. These bops are controlled by hydraulics. It could have been a hydraulic ram faliure. A Hose could have ruptured not giving the ram enough hydraulic pressure to close the ram and cut the pipe.
I am not even sure if a drill string was across the bop rams. I am just suggesting a few possible reasons to answer your question if something was indeed across the rams when the failure occured.
Posted on 5/2/10 at 4:40 pm to shaunk128
quote:
It is possible that some heavy wall pipe was across the bops and the bops could not cut it.
it is possible that the tool jt was in line with the shears. however, the guy interviewed stated that the gas hit them before they knew it. so, i doubt that the rams were ever shut.
Posted on 5/2/10 at 4:42 pm to Oyster
quote:
Oyster
Thanks
Posted on 5/2/10 at 4:58 pm to shaunk128
prolly a dumb question, but did the rig sink due to damage from the fire or from being inundated with seawater from firefighting vessels?
in other words, could the massive spill have been avoided if the fire had continued at the rig/the surface?
obviously the rig couldn't hold up forever with that kind of heat..
in other words, could the massive spill have been avoided if the fire had continued at the rig/the surface?
obviously the rig couldn't hold up forever with that kind of heat..
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