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Started By
Message
re: if top kill fails-keep pumping sea water
Posted on 5/29/10 at 8:57 pm to RighteousTiger
Posted on 5/29/10 at 8:57 pm to RighteousTiger
True Vertical Depth
0
Posted on 5/29/10 at 9:03 pm to RighteousTiger
quote:
What the hell is TVD? "Total Volume Dispersed"?
The formula he posted earlier was the means to calculate the head you are generating.
.053 times the true vertical depth times the mud weight
This post was edited on 5/29/10 at 9:05 pm
Posted on 5/29/10 at 9:13 pm to Volvagia
Thanks for the info
Posted on 5/29/10 at 9:19 pm to redstick13
quote:Or surface pressure...
You can only increase MW to saturation point and if that doesn't help then the only other thing you can do is increase TVD.
BHP = 0.052 * MW * TVD + Surface Pressure
Posted on 5/29/10 at 9:19 pm to RighteousTiger
They are likely using a Hematite based mud since it has a higher S.G. than Barite. Hematite mud can be weighted to 25 lb/gal.
So that means the pressure at the wellhead is likely around 6500 psi.
So that means the pressure at the wellhead is likely around 6500 psi.
This post was edited on 5/29/10 at 9:23 pm
Posted on 5/29/10 at 9:21 pm to Bayou Tiger
quote:
Or surface pressure...
BHP = 0.052 * MW * TVD + Surface Pressure
True but with an open annulus you cannot generate any back pressure.
Posted on 5/29/10 at 9:32 pm to redstick13
May be an ignorant question here, but if overburden gradient is roughly 1 psi/ft (~19 ppg), how can a formation be so overpressured at that depth? Not to mention a significant portion of the "overburden" is a column of ocean water(8.6 ppg).
Posted on 5/29/10 at 9:34 pm to Bayou Tiger
quote:
May be an ignorant question here, but if overburden gradient is roughly 1 psi/ft (~19 ppg), how can a formation be so overpressured at that depth? Not to mention a significant portion of the "overburden" is a column of ocean water(8.6 ppg)
That's overburden, not pore pressure. Plus, gas expands as it comes to the surface.
This post was edited on 5/29/10 at 9:38 pm
Posted on 5/29/10 at 9:36 pm to redstick13
quote:Sure. I just saw a reference to 25 ppg mud to kill it. Do you happen to know the EMW of the formation (relative to mud line or sea level)? You seem to have a good feel for the situation.
That's overburden, not pore pressure. Plus gas expands as it comes to the surface.
Posted on 5/29/10 at 9:41 pm to Bayou Tiger
quote:
Sure. I just saw a reference to 25 ppg mud to kill it. Do you happen to know the EMW of the formation (relative to mud line or sea level)? You seem to have a good feel for the situation.
Sorry I don't know that. I would need access to more information than what I have to do some pore pressure calculations. If BP ran a formation pressure tool in the LWD string or on wireline they should know exactly what type of pressures they are dealing with.
Obviously the pressure at the mud line has to be more than 6500 psi. I can make a guess and say it's likely less than 15,000 psi. Probably less than 10,000 psi.
Posted on 5/29/10 at 9:44 pm to redstick13
I guess if we knew the TVD of the formation and the weight of the fluid in the hole we could estimate FHBP and back it out.
Posted on 5/29/10 at 9:46 pm to Bayou Tiger
quote:
I guess if we knew the TVD of the formation and the weight of the fluid in the hole we could estimate FHBP and back it out.
We really only need the mud weight they used to TD the well and the TVD. However, I don't have that either.
Posted on 5/29/10 at 9:53 pm to redstick13
Here's the formula we use to calculate kill mud weight during a kick.
Kill Mud Weight = Shut-in Drill Pipe Pressure / 0.052 / TVD + Original Mud Weight.
So yes, we need to know the Original Mud Weight and TVD.
Here's a big problem though. Since the well blew out from behind the casing, who knows what the fluid density behind casing was?
Kill Mud Weight = Shut-in Drill Pipe Pressure / 0.052 / TVD + Original Mud Weight.
So yes, we need to know the Original Mud Weight and TVD.
Here's a big problem though. Since the well blew out from behind the casing, who knows what the fluid density behind casing was?
Posted on 5/29/10 at 9:56 pm to redstick13
Also, it didn't blow out when they drilled into it with mud. It blew out against seawater in the hole.
Posted on 5/29/10 at 9:58 pm to redstick13
the well was td'd w/ 14.0 ppg at 18300' and the well was under control w/ that mudweight -- enough to run casing.
you'd need ~16.0 ppg to dynamically kill it from bottom while still open to SW at the wellhead.
you'd need ~16.0 ppg to dynamically kill it from bottom while still open to SW at the wellhead.
Posted on 5/29/10 at 10:01 pm to Bayou Tiger
Well it blew out against the sea water in the riser and whatever was behind the tapered casing string.
I'm looking at the prog now and it called for a 14.00 ppg MW at TD and they estimated the pore pressure would be 12.5 to 13.9 ppg.
I'm looking at the prog now and it called for a 14.00 ppg MW at TD and they estimated the pore pressure would be 12.5 to 13.9 ppg.
Posted on 5/29/10 at 10:03 pm to oilfieldtiger
quote:
the well was td'd w/ 14.0 ppg at 18300' and the well was under control w/ that mudweight -- enough to run casing.
you'd need ~16.0 ppg to dynamically kill it from bottom while still open to SW at the wellhead.
Thanks oifieldtiger, you beat me to it. From bottom being the key words here.
Posted on 5/29/10 at 10:06 pm to oilfieldtiger
quote:Thanks, dude
the well was td'd w/ 14.0 ppg at 18300' and the well was under control w/ that mudweight -- enough to run casing.
you'd need ~16.0 ppg to dynamically kill it from bottom while still open to SW at the wellhead.
Posted on 5/29/10 at 10:07 pm to redstick13
i've said before on here, but i think i'd try to circulate freshwater through the system and induce hydrates throughout the system.
i know everyone who's worked w/ subsea systems knows just how surprisingly strong a hydrate plug can be.
i know everyone who's worked w/ subsea systems knows just how surprisingly strong a hydrate plug can be.
Posted on 5/29/10 at 10:12 pm to oilfieldtiger
You think they could induce a hydrate plug in the BOP?
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