BP Deepwater Horizon Downhole Blowout Worst Case Scenario – Well Spews Oil Out With No Closing.

Posted: June 13th, 2010 by: h2

Here’s another posting that got lost in theOilDrum.com comment thread Deepwater Oil Spill – A Longer Term Problem, Personnel – and Open Thread 2

I’ve corrected a few factual errors, and those corrections will appear in […] in the quote body, and I’ve also cleaned up the links/quotes to make them more readable. Other than that all content is as it appeared Saturday night. Please note that the original source for this was as far as I can tell on godlikeproductions.com/forum1/ – The BP Deep water horizon, Macondo Well Blowout. and what we are facing in the Gulf Part II

A similar discussion/posting of a casing failure can be found at nakedcapitalism.com – Guest Post: BP Official Admits to Damage BENEATH THE SEA FLOOR, June 12 2010, with relevant quotes and support arguments.

Also, you have to wonder if this is what Matt Simmons (Oil Guru: The Real Nightmare Will Be When A Hurricane Picks Up The Oil And Paints The Gulf Coast Black, The Gulf Coast oil spill’s Dr. Doom, and theOilDrum.com – Matt Simmons on Dylan Ratigan Today, Closing the Relief Ports, and Open Thread 2) and Florida senator Bill Nelson (Sen. Bill Nelson: Reports of oil seeping up from seabed, well casing may be pierced. (video) ), were talking about recently, albeit in a distorted form?

Also please make sure to read the discussion I’ve posted under this main article/posting that looks at some of the key points from a technical perspective.

dougr on June 13, 2010 – 3:17am Permalink | Subthread | Comments top

OK let’s get real about the GOM oil flow. There doesn’t really seem to be much info on TOD that furthers more complete understanding of what’s really happening in the GOM.

As you have probably seen and maybe feel yourselves, there are several things that do not appear to make sense regarding the actions of attack against the well. Don’t feel bad, there is much that doesn’t make sense even to professionals unless you take into account some important variables that we are not being told about. There seems to me to be a reluctance to face what cannot be termed anything less than grim circumstances in my opinion. There certainly is a reluctance to inform us regular people and all we have really gotten is a few dots here and there…

First of all…set aside all your thoughts of plugging the well and stopping it from blowing out oil using any method from the top down. Plugs, big valves to just shut it off, pinching the pipe closed, installing a new bop or lmrp, shooting any epoxy in it, top kills with mud etc etc etc….forget that, it won’t be happening..it’s done and over. In fact actually opening up the well at the subsea source and allowing it to gush more is not only exactly what has happened, it was probably necessary, or so they think anyway.

So you have to ask WHY? Why make it worse?…there really can only be one answer and that answer does not bode well for all of us. It’s really an inescapable conclusion at this point, unless you want to believe that every Oil and Gas professional involved suddenly just forgot everything they know or woke up one morning and drank a few big cups of stupid and got assigned to directing the response to this catastrophe. Nothing makes sense unless you take this into account, but after you do…you will see the “sense” behind what has happened and what is happening. That conclusion is this:

The well bore structure is compromised “Down hole”.

That is something which is a “Worst nightmare” conclusion to reach. While many have been saying this for some time as with any complex disaster of this proportion many have “said” a lot of things with no real sound reasons or evidence for jumping to such conclusions, well this time it appears that they may have jumped into the right place…

This was probably our best and only chance to kill this well from the top down. This “kill mud” is a tried and true method of killing wells and usually has a very good chance of success. The depth of this well presented some logistical challenges, but it really should not of presented any functional obstructions. The pumping capacity was there and it would have worked, should have worked, but it didn’t.

It didn’t work, but it did create evidence of what is really happening. First of all the method used in this particular top kill made no sense, did not follow the standard operating procedure used to kill many other wells and in fact for the most part was completely contrary to the procedure which would have given it any real chance of working.

When a well is “Killed” using this method heavy drill fluid “Mud” is pumped at high volume and pressure into a leaking well. The leaks are “behind” the point of access where the mud is fired in, in this case the “choke and Kill lines” which are at the very bottom of the BOP (Blow Out Preventer) The heavy fluid gathers in the “behind” portion of the leaking well assembly, while some will leak out, it very quickly overtakes the flow of oil and only the heavier mud will leak out. Once that “solid” flow of mud is established at the leak “behind” the well, the mud pumps increase pressure and begin to overtake the pressure of the oil deposit. The mud is established in a solid column that is driven downward by the now stronger pumps. The heavy mud will create a solid column that is so heavy that the oil deposit can no longer push it up, shut off the pumps…the well is killed…it can no longer flow.

Usually this will happen fairly quickly, in fact for it to work at all…it must happen quickly. There is no “trickle some mud in” because that is not how a top kill works. The flowing oil will just flush out the trickle and a solid column will never be established. Yet what we were told was “It will take days to know whether it worked”….”Top kill might take 48 hours to complete”…the only way it could take days is if BP intended to do some “test fires” to test integrity of the entire system. The actual “kill” can only take hours by nature because it must happen fairly rapidly. It also increases strain on the “behind” portion and in this instance we all know that what remained was fragile at best.

Early that afternoon we saw a massive flow burst out of the riser “plume” area. This was the first test fire of high pressure mud injection. Later on same day we saw a greatly increased flow out of the kink leaks, this was mostly mud at that time as the kill mud is tanish color due to the high amount of Barite which is added to it to weight it and Barite is a white powder.

We later learned the pumping was shut down at midnight, we weren’t told about that until almost 16 hours later, but by then…I’m sure BP had learned the worst. The mud they were pumping in was not only leaking out the “behind” leaks…it was leaking out of someplace forward…and since they were not even near being able to pump mud into the deposit itself, because the well would be dead long before…and the oil was still coming up, there could only be one conclusion…the wells casings were ruptured and it was leaking “down hole”

They tried the “Junk shot”…the “bridging materials” which also failed and likely made things worse in regards to the ruptured well casings.

“Despite successfully pumping a total of over 30,000 barrels of heavy mud, in three attempts at rates of up to 80 barrels a minute, and deploying a wide range of different bridging materials, the operation did not overcome the flow from the well.”
bp.com – Update on Gulf of Mexico Oil Spill – 29 May

80 Barrels per minute is over 200,000 gallons per hour, over 115,000 barrels per day…did we seen an increase over and above what was already leaking out of 115k bpd?….we did not…it would have been a massive increase in order of multiples and this did not happen.

“The whole purpose is to get the kill mud down,” said Wells. “We’ll have 50,000 barrels of mud on hand to kill this well. It’s far more than necessary, but we always like to have backup.”
Houston Chronicle – Some good news from the depths
4-inch tube successfully threaded into pipeline, begins syphoning oil, May 17 2010

Try finding THAT quote around…it’s been scrubbed…here’s a cached copy of a quote…
[Note: it was easy to find a sourced copy of that quote, let’s not get carried away with conspiracy thinking when it’s not needed:]

“The “top kill” effort, launched Wednesday afternoon by industry and government engineers, had pumped enough drilling fluid to block oil and gas spewing from the well, Allen said. The pressure from the well was very low, he said, but persisting.”

“Allen said one ship that was pumping fluid into the well had run out of the fluid, or “mud,” and that a second ship was on the way. He said he was encouraged by the progress.”
houmatoday.com – Top kill’ plugs gulf oil leak, official says, May 27

Later we found out that Allen had no idea what was really going on and had been “Unavailable all day”
realclearpolitics.com – Interview with Coast Guard Admiral Thad Allen, May 27

So what we had was BP running out of 50,000 barrels of mud in a very short period of time. An amount far and above what they deemed necessary to kill the well. Shutting down pumping 16 hours before telling anyone, including the president. We were never really given a clear reason why “Top Kill” failed, just that it couldn’t overcome the well.

There is only one article anywhere that says anything else about it at this time of writing…and it’s a relatively obscure article from the wall street journal “online” citing an unnamed source.

“WASHINGTON—BP PLC has concluded that its “top-kill” attempt last week to seal its broken well in the Gulf of Mexico may have failed due to a malfunctioning disk inside the well about 1,000 feet below the ocean floor.

The disk, part of the subsea safety infrastructure, may have ruptured during the surge of oil and gas up the well on April 20 that led to the explosion aboard the Deepwater Horizon rig, BP officials said. The rig sank two days later, triggering a leak that has since become the worst in U.S. history.

The broken disk may have prevented the heavy drilling mud injected into the well last week from getting far enough down the well to overcome the pressure from the escaping oil and gas, people familiar with BP’s findings said. They said much of the drilling mud may also have escaped from the well into the rock formation outside the wellbore.

As a result, BP wasn’t able to get sufficient pressure to keep the oil and gas at bay. If they had been able to build up sufficient pressure, the company had hoped to pump in cement and seal off the well. The effort was deemed a failure on Saturday.

BP started the top-kill effort Wednesday afternoon, shooting heavy drilling fluids into the broken valve known as a blowout preventer. The mud was driven by a 30,000 horsepower pump installed on a ship at the surface. But it was clear from the start that a lot of the “kill mud” was leaking out instead of going down into the well.”
online.wsj.com – BP Cites Broken Disk in ‘Top Kill’ Failure, June 2

There are some inconsistencies with this article.
There are no “Disks” or “Subsea safety structure” 1,000 feet below the sea floor, all that is there is well bore. There is nothing that can allow the mud or oil to “escape” into the rock formation outside the well bore except the well, because it is the only thing there.

All the actions and few tid bits of information all lead to one inescapable conclusion. The well pipes below the sea floor are broken and leaking. Now you have some real data of how BP’s actions are evidence of that, as well as some murky statement from “BP officials” confirming the same.

I took some time to go into a bit of detail concerning the failure of Top Kill because this was a significant event. To those of us outside the real inside loop, yet still fairly knowledgeable, it was a major confirmation of what many feared. That the system below the sea floor has serious failures of varying magnitude in the complicated chain, and it is breaking down and it will continue to.

What does this mean?

It means they will never cap the gusher after the wellhead. They cannot…the more they try and restrict the oil gushing out the bop?…the more it will transfer to the leaks below. Just like a leaky garden hose with a nozzle on it. When you open up the nozzle?…it doesn’t leak so bad, you close the nozzle?…it leaks real bad, same dynamics. It is why they sawed the riser off…or tried to anyway…but they clipped it off, to relieve pressure on the leaks “down hole”. I’m sure there was a bit of panic time after they crimp/pinched off the large riser pipe and the Diamond wire saw got stuck and failed…because that crimp diverted pressure and flow to the rupture down below.

Contrary to what most of us would think as logical to stop the oil mess, actually opening up the gushing well and making it gush more became direction BP took after confirming that there was a leak. In fact if you note their actions, that should become clear. They have shifted from stopping or restricting the gusher to opening it up and catching it. This only makes sense if they want to relieve pressure at the leak hidden down below the seabed…..and that sort of leak is one of the most dangerous and potentially damaging kind of leak there could be. It is also inaccessible which compounds our problems. There is no way to stop that leak from above, all they can do is relieve the pressure on it and the only way to do that right now is to open up the nozzle above and gush more oil into the gulf and hopefully catch it, which they have done, they just neglected to tell us why, gee thanks.

A down hole leak is dangerous and damaging for several reasons.

There will be erosion throughout the entire beat up, beat on and beat down remainder of the “system” including that inaccessible leak. The same erosion I spoke about in the first post is still present and has never stopped, cannot be stopped, is impossible to stop and will always be present in and acting on anything that is left which has crude oil “Product” rushing through it. There are abrasives still present, swirling flow will create hot spots of wear and this erosion is relentless and will always be present until eventually it wears away enough material to break it’s way out. It will slowly eat the bop away especially at the now pinched off riser head and it will flow more and more. Perhaps BP can outrun or keep up with that out flow with various suckage methods for a period of time, but eventually the well will win that race, just how long that race will be?…no one really knows….However now?…there are other problems that a down hole leak will and must produce that will compound this already bad situation.

This down hole leak will undermine the foundation of the seabed in and around the well area. It also weakens the only thing holding up the massive Blow Out Preventer’s immense bulk of 450 tons. In fact?…we are beginning to the results of the well’s total integrity beginning to fail due to the undermining being caused by the leaking well bore.

The first layer of the sea floor in the gulf is mostly lose material of sand and silt. It doesn’t hold up anything and isn’t meant to, what holds the entire subsea system of the Bop in place is the well itself. The very large steel connectors of the initial well head “spud” stabbed in to the sea floor. The Bop literally sits on top of the pipe and never touches the sea bed, it wouldn’t do anything in way of support if it did. After several tens of feet the seabed does begin to support the well connection laterally (side to side) you couldn’t put a 450 ton piece of machinery on top of a 100′ tall pipe “in the air” and subject it to the side loads caused by the ocean currents and expect it not to bend over…unless that pipe was very much larger than the machine itself, which you all can see it is not. The well’s piping in comparison is actually very much smaller than the Blow Out Preventer and strong as it may be, it relies on some support from the seabed to function and not literally fall over…and it is now showing signs of doing just that….falling over.

If you have been watching the live feed cams you may have noticed that some of the ROVs are using an inclinometer…and inclinometer is an instrument that measures “Incline” or tilt. The BOP is not supposed to be tilting…and after the riser clip off operation it has begun to…

This is not the only problem that occurs due to erosion of the outer area of the well casings. The way a well casing assembly functions it that it is an assembly of different sized “tubes” that decrease in size as they go down. These tubes have a connection to each other that is not unlike a click or snap together locking action. After a certain length is assembled they are cemented around the ouside to the earth that the more rough drill hole is bored through in the well making process. A very well put together and simply explained process of “How to drill a deep water oil well” is available here:
treesfullofmoney.com – An Introduction to Drilling Offshore Oil Wells, April 2 2010

The well bore casings rely on the support that is created by the cementing phase of well construction. Just like if you have many hands holding a pipe up you could put some weight on the top and the many hands could hold the pipe and the weight on top easily…but if there were no hands gripping and holding the pipe?…all the weight must be held up by the pipe alone. The series of connections between the sections of casings are not designed to hold up the immense weight of the BOP without all the “hands” that the cementing provides and they will eventually buckle and fail when stressed beyond their design limits.

These are clear and present dangers to the battered subsea safety structure (bop and lmrp) which is the only loose cork on this well we have left. The immediate (first 1,000 feet) of well structure that remains is now also undoubtedly compromised. However…..as bad as that is?…it is far from the only possible problems with this very problematic well. There were ongoing troubles with the entire process during the drilling of this well. There were also many comprises made by BP IMO which may have resulted in an overall weakened structure of the entire well system all the way to the bottom plug which is over 12,000 feet deep. Problems with the cementing procedure which was done by Haliburton and was deemed as “was against our best practices.” by a Haliburton employee on April 1st weeks before the well blew out. There is much more and I won’t go into detail right now concerning the lower end of the well and the troubles encountered during the whole creation of this well and earlier “Well control” situations that were revieled in various internal BP e-mails. I will add several links to those documents and quotes from them below and for now, address the issues concerning the upper portion of the well and the region of the sea floor.

What is likely to happen now?

Well…none of what is likely to happen is good, in fact…it’s about as bad as it gets. I am convinced the erosion and compromising of the entire system is accelerating and attacking more key structural areas of the well, the blow out preventer and surrounding strata holding it all up and together. This is evidenced by the tilt of the blow out preventer and the erosion which has exposed the well head connection. What eventually will happen is that the blow out preventer will literally tip over if they do not run supports to it as the currents push on it. I suspect they will run those supports as cables tied to anchors very soon, if they don’t, they are inviting disaster that much sooner.

Eventually even that will be futile as the well casings cannot support the weight of the massive system above with out the cement bond to the earth and that bond is being eroded away. When enough is eroded away the casings will buckle and the BOP will collapse the well. If and when you begin to see oil and gas coming up around the well area from under the BOP? or the area around the well head connection and casing sinking more and more rapidly? …it won’t be too long after that the entire system fails. BP must be aware of this, they are mapping the sea floor sonically and that is not a mere exercise. Our Gov’t must be well aware too, they just are not telling us.

All of these things lead to only one place, a fully wide open well bore directly to the oil deposit…after that, it goes into the realm of “the worst things you can think of” The well may come completely apart as the inner liners fail. There is still a very long drill string in the well, that could literally come flying out…as I said…all the worst things you can think of are a possibility, but the very least damaging outcome as bad as it is, is that we are stuck with a wide open gusher blowing out 150,000 barrels a day of raw oil or more. There isn’t any “cap dome” or any other suck fixer device on earth that exists or could be built that will stop it from gushing out and doing more and more damage to the gulf. While at the same time also doing more damage to the well, making the chance of halting it with a kill from the bottom up less and less likely to work, which as it stands now?….is the only real chance we have left to stop it all.

It’s a race now…a race to drill the relief wells and take our last chance at killing this monster before the whole weakened, wore out, blown out, leaking and failing system gives up it’s last gasp in a horrific crescendo.

We are not even 2 months into it, barely half way by even optimistic estimates. The damage done by the leaked oil now is virtually immeasurable already and it will not get better, it can only get worse. No matter how much they can collect, there will still be thousands and thousands of gallons leaking out every minute, every hour of every day. We have 2 months left before the relief wells are even near in position and set up to take a kill shot and that is being optimistic as I said.

Over the next 2 months the mechanical situation also cannot improve, it can only get worse, getting better is an impossibility. While they may make some gains on collecting the leaked oil, the structural situation cannot heal itself. It will continue to erode and flow out more oil and eventually the inevitable collapse which cannot be stopped will happen. It is only a simple matter of who can “get there first”…us or the well.

We can only hope the race against that eventuality is one we can win, but my assessment I am sad to say is that we will not.

The system will collapse or fail substantially before we reach the finish line ahead of the well and the worst is yet to come.

Sorry to bring you that news, I know it is grim, but that is the way I see it….I sincerely hope I am wrong.

We need to prepare for the possibility of this blow out sending more oil into the gulf per week then what we already have now, because that is what a collapse of the system will cause. All the collection efforts that have captured oil will be erased in short order. The magnitude of this disaster will increase exponentially by the time we can do anything to halt it and our odds of actually even being able to halt it will go down.

The magnitude and impact of this disaster will eclipse anything we have known in our life times if the worst or even near worst happens…

We are seeing the puny forces of man vs the awesome forces of nature.
We are going to need some luck and a lot of effort to win…
and if nature decides we ought to lose, we will….

Reference materials:

On April 1, a job log written by a Halliburton employee, Marvin Volek, warns that BP’s use of cement “was against our best practices.”

An April 18 internal Halliburton memorandum indicates that Halliburton again warned BP about its practices, this time saying that a “severe” gas flow problem would occur if the casings were not centered more carefully.

Around that same time, a BP document shows, company officials chose a type of casing with a greater risk of collapsing.
nytimes.com – In Gulf, It Was Unclear Who Was in Charge of Rig, June 5 2010

Mark Hafle, the BP drilling engineer who wrote plans for well casings and cement seals on the Deepwater Horizon’s well, testified that the well had lost thousands of barrels of mud at the bottom. But he said models run onshore showed alterations to the cement program would resolve the issues, and when asked if a cement failure allowed the well to “flow” gas and oil, he wouldn’t capitulate.

Hafle said he made several changes to casing designs in the last few days before the well blew, including the addition of the two casing liners that weren’t part of the original well design because of problems where the earthen sides of the well were “ballooning.” He also worked with Halliburton engineers to design a plan for sealing the well casings with cement.
nola.com – Hearings: BP cementing engineer rejects suggestion his actions led to disaster, May 28 2010

graphic of fail
media.nola.com – oil-cause-050710.pdf (PDF file)

Casing joint


Kill may take until Christmas
Bloomberg.com – BP Oil Leak May Last Until Christmas in Worst Case Scenario, June 2 2010

BP Used Riskier Method to Seal Well Before Blast
nytimes.com – BP Used Riskier Method to Seal Well Before Blast, May 26 2010

BP memo test results
energycommerce.house.gov – (PDF file)

Investigation results

The information from BP identifies several new warning signs of problems. According to BP there were three flow indicators from the well before the explosion.
energycommerce.house.gov – (PDF file)

BP, what we know
energycommerce.house.gov – (PDF file)

What could have happened

1. Before or during the cement job, an influx of hydrocarbon enters the wellbore.
2. Influx is circulated during cement job to wellhead and BOP.
3. 9-7/8” casing hanger packoff set and positively tested to 6500 psi.
4. After 16.5 hours waiting on cement, a negative test performed on wellbore below BOP. (~ 1400 psi differential pressure on 9-7/8” casing hanger packoff and ~ 2350 psi on double valve float collar)
5. Packoff leaks allowing hydrocarbon to enter wellbore below BOP. 1400 psi shut in pressure observed on drill pipe (no flow or pressure observed on kill line)
6. Hydrocarbon below BOP is unknowingly circulated to surface while finishing displacing the riser.
7. As hydrocarbon rises to surface, gas break out of solution further reduces hydrostatic pressure in well. Well begin to flow, BOPs and Emergency Disconnect System (EDS) activated but failed.
8. Packoff continues to leak allowing further influx from bottom.
Confidential. BP. What Could Have Happened
energycommerce.house.gov – (PDF file)

T/A daily log 4-20
energycommerce.house.gov – (PDF file)

Cement plug 12,150 ft SCMT logging tool
SCMT (Slim Cement Mapping Tool)
Schlumberger Partial CBL done.
energycommerce.house.gov – (PDF file)

Schlum CBL tools
slb.com – cement_bond_logging_tools.ashx

Major concerns, well control, bop test.
energycommerce.house.gov – (PDF file)

Energy & commerce links to docs.

well head on sea floor
nca-group.com – jpg image

Well head on deck of ship
nca-group.com – jpg image

BP’s youtube propoganda page, a lot of rarely seen vids here….FWIW
youtube.com –
Deepwater Horizon Oil Spill
DeepwaterHorizonJIC’s Channel

godlikeproductions.com – The BP Deep water horizon, Macondo Well Blowout. and what we are facing in the Gulf Part II [Note: This appears to be the source of the original posting, which suggests dougr took it from there, or is SHR himself.

I used to cover the energy business (oil, gas and alternative) here in Texas, and the few experts in the oil field — including geologists, chemists, etc. — able or willing to even speak of this BP event told me early on that it is likely the entire reserve will bleed out. Unfortunately none of them could say with any certainty just how much oil is in the reserve in question because, for one thing, the oil industry and secrecy have always been synonymous. According to BP data from about five years ago, there are four separate reservoirs containing a total of 2.5 billion barrels (barrels not gallons). One of the reservoirs has 1.5 billion barrels. I saw an earlier post here quoting an Anadarko Petroleum report which set the total amount at 2.3 billion barrels. One New York Times article put it at 2 billion barrels.

If the BP data correctly or honestly identified four separate reservoirs then a bleed-out might gush less than 2 to 2.5 billion barrels unless the walls — as it were — fracture or partially collapse. I am hearing the same dark rumors which suggest fracturing and a complete bleed-out are already underway. Rumors also suggest a massive collapse of the Gulf floor itself is in the making. They are just rumors but it is time for geologists or related experts to end their deafening silence and speak to these possibilities.

All oilmen lie about everything. The stories one hears about the extent to which they will protect themselves are all understatements. BP employees are already taking The Fifth before grand juries, and attorneys are laying a path for company executives to make a run for it.

Because of the length of the above posting, I’m including the license terms of this posting.

All content at theOilDrum.com is released under the Creative Commons License

This work is licensed under a Creative Commons Attribution-Share Alike 3.0 United States License.

Further Discussion of Technical Merits of this Claim on GodlikeProductions.com

grey wolf – 6/13/2010 10:10 AM – Page 15
Some thoughts after reading some of the replies…………

1. With respect to the plans for controlling the well post blowout, not much has changed over the past 31 years. Please see wimp.com/oilspills/. You will understand what I’m talking about after viewing.

2. Most folks think this was an extremely poor well design, i.e. no second barrier to protect the surface/environment from the reservoir (not deposit). You could call it a deposit, but in the industry, we call it a reservoir. If you need more evidence of this, please see the BP report presented on Capitol Hill. I believe you have posted the link. Pay particular attention to the slides detailing the well itself.

3. It’s believed that there are burst disks in the casing strings tied back to surface. Your presumption that a well integrity problem exists is spot on, only the wrong presumption! Please see the presentation mentioned in #2.

4. The well is 13,000 ft below the mudline. Add in the depth of the water and you get ~18,000 ft. According to the slide noted in #2 above, the well was drilled with a 14.9 ppg mud, which equates to a hydrostatic pressure of ~13,900 psi. Typically, wells are drilled in an overbalanced situation, say 200 psi or so, the pore pressure is ~ 14.7 ppg. To quote one of the posters “It has been estimated by experts that the pressure which blows the oil into the Gulf waters is estimated to be between 20,000 and 70,000 PSI (pounds per square inch). Impossible to control.” This statement is complete and absolute bullshit.

5. As noted in BP’s presentation to Capitol Hill, there were 3 instances where this event could have been controlled prior to the blowout! Well control events don’t just happen! There are always indications prior to an event. You did speak about this.

6. The drilling rig contractor’s Offshore Installation Manager (OIM) appears to have caved in to pressure from the BP company man. If he hadn’t, this wouldn’t be a thread today! Do a search in Wikipedia for the role and function of the OIM, it might enlighten you. I’m not a big fan of Wiki, but it does provide an adequate description of the function of the OIM.

7. Why wasn’t there a BP company man on the rig floor during a well control event? This isn’t standard operating procedure. Company men / foremen have well control training as well as personnel on the rig floor.

8. There are usually a minimum of two (2) inclinometers on the BOP. Unless you are looking directly down on them, you can’t tell if the wellhead is leaning or not. ROV’s rarely stay perfectly horizontal so using the ROV inclinometer is a stretch at best. One really has to understand the inclination of the wellhead prior to the blowout to make any inferences as to it’s current state. It wouldn’t be a surprise if there is some tilt, of the wellhead. Recall the explosions left the rig dead in the water, it’s a dynamic postioned (DP) vessel, currents would then begin to push it off location. The riser is still attached at two (2) points, the rig, and the BOP. The shear weight of the vessel and the riser being forced off location may indeed impart bending moments at the sea floor, which in turn may cause the wellhead to lean some-what.

9. With respect to subsea currents toppling the BOP stack…. Currents subsea are usually pretty much benign (< 2 knots), unless the wellhead location is in the loop current where they can get greater, +/- 6 knots. These higher currents, usually at much shallower depths than the wellhead play havoc with riser systems and usually induce what is called Vortex Induced Vibration (VIV). VIV induces oscillation in the risers. VIV makes landing the BOP on the wellhead a challenge, but once it is landed and locked typically has little impact. 10. There is some mention of the failed BOP’s, but there is no mention of the findings when the riser was cut just above the tension joint. Wanna know? There were two (2) pieces of drill pipe in the riser. Yes Virginia, there should have been only one (1). Obviously this hasn’t been made public and could potentially explain some of the malfunctions that occurred with the BOP. We’ll know for sure once the BOP’s are recovered and evaluated. 11. Casing strings are not “snapped” together. Typically, they are a premium threaded connection rated for a pre-specified pressure. This means they are screwed together to a specified torque using calibrated tongs. 12. Workstring or drill pipe can be cut with shear rams in most instances. What can’t be sheared are the tool joints between each piece of drill pipe (30’ lengths). They typically have a smaller ID and larger OD than the tubes themselves (makes the connection stronger than the tube body). The increase in wall thickness is a known problem with respect to the BOP blind/shear rams being able to severe them. 13. There are a couple variations of Deadman systems. Some are hydraulic and others acoustic. It’s common knowledge that the hydraulic systems are more reliable than acoustic. Think about it, direct hydraulics, vs. something that depends on sound waves (a transmitter and receiver, two (2) additional failure points)!!! An additional cost of $500k for something that may / may not function when needed. 14. Big misconception. “relief well drilled to relieve pressure”, NOT. They won’t relieve any pressure, they will pump heavy mud in the failed wellbore to kill the well, then follow it with cement to stop the flow of hydrocarbon. Once the well is dead, equipment will start to be recovered. Key pieces are of course the BOP, LMRP, and potentially the wellhead. This will take some time. 15. John Q. Public should be assured that the BOP’s will be dissected to understand what worked and didn’t work and why. Notice I didn’t say fail, because we don’t know what was across them when activated. Obviously the LMRP didn’t disconnect when the EQD was activated. They will have to be torn down and evaluated to understand what worked/didn’t work. 16. With respect to erosion, maybe / maybe not. The formation containing the hydrocarbons appears to be fairly competent rock (Miocene age). What is meant by this is the rock has good cementation qualities, i.e. the sand grains are held together with minute particles of cement yielding excellent compressive strength. Yes, there is porosity (pore spaces available to contain the oil, and excellent permeability. Permeability is a measure of the ease with which fluid can move from point A to point B with an induced pressure drop from A to B. 17. The well will then be plugged and abandoned. It will never be a producer. 18. The only sure way to remediate this problem is the relief well. Yes it will take some time to happen, but it will happen. Understand what the directional drillers are trying to do, basically hit a target in the earth the size of a dinner plate 18,000 feet away (3.4 miles). Not easy, but it can be done. Enough for now as I’m sure this will spur additional questions……………….grey wolf =====

grey wolf 6/13/2010 7:14 PM

“Grey Wolf, do you think there is danger of this well getting even more out of control before the relief wells are finished? If you addressed this in your post and I didn’t understand it please forgive….just wondering if those who say we could be dealing with sea floor collapse, dramatically increased flows, etc. are correct. Thanks.”

There is always a danger of things getting worse before they get better. Sea floor collapse could result from subsidence, unless there is an issue (or leak) somewheres beneath the drive pipe. Drive pipe is the first string of casing run. It extends from the sea floor to about 500’ or so beneath it and is cemented in. Next comes surface casing, its depth varies depending on pore pressure. Following this string of pipe is 20” or 26” which may have the wellhead on top. It’s cemented in and provide stability for the BOP’s.

“What I understand is that there is the belief that there is no way that this problem can’t be solved and also if we understand this correctly, there is no possibility of a gloom and doom event.”

Everything can be solved with time and money.

“If this thread is still about oil, some congressman (forgot his name between the TV and here) just said on Fox that relief wells haven’t even been started. The host quickly dismissed it and said it wasn’t true and that the well(s) will be ready by August.”

The last time I checked, the first relief well as approaching 14,000 ft MD, and the second was nearing 8500’ MD. Water depth is 5000’ so it seems to me they have been drilling for some time.

“You say that a typical well of this depth must be less than 14,000 psi. But please address the following two points:

a. There are rumors that BP drilled much deeper than they were permitted. If true, and I have no way to know, that would lead the “typical” pressure to be greater, would it not?

b. It has also been hypothesized that BP drilled into a soft formation. Hence the cracking as oil and methane escape the reservoir, as the reservoir roof = sea bed collapses.

If the top (being soft) is essentially floating on the reservoir, rather than (if it were rigid) being supported laterally from the sides, then the reservoir pressure equals the weight per unit area pressing down on it. Assuming (consistent with BP’s statements and what they are permitted to drill) the sea floor is one mile deep and the reservoir is two miles deeper than that, and using Schlumberger’s rough estimate that rock is three times denser than water, I have calculated this pressure to be over 20,000 psi. That number would go up roughly proportional to the depth of rock between the sea floor and the top of the reservoir.”

A. Unsure as to what you consider as “much deeper than permitted”. Prudent operator’s do not violate the law with out first notifying the regulatory agency of their intention.
B. It’s bullshit. Define soft formation! Keep in mind that we are talking about Miocene age rock which happens to be some 24-65 million years ago. Deposits from the Mississippi river have settled creating structure and trap, the microorganisms have created hydrocarbons. Seawater in the Please refer to the BP presentation to Capitol Hill for formation pressure.

“ls this a 100% certainty? ls there any possibility at all this will not work”?

The only thing that is 100% certain as a US citizen is death and taxes. If they don’t hit it on the first attempt, they will sidetrack and try again. Directional drilling in today’s environment is quite good. Keep in mind they have to hit a dinner plate 18,000 ft away. I’d take that bet in Vegas.

“”ROV films oil leak coming from rock cracks on seafloor”

Interesting development if it’s true. Just checked the live feeds, and they aren’t looking at the seafloor, primarily BOPs and that stuff. It appears as though some of the ROVs are out of the water getting mainenence of some sort.

“my question is this what exactly is the pressure at the sea floor sea level?

(5000’)*(8.6 #/gal)*(0.052 psi/ft) = 2236 psi at the sea floor

“Grey Wolf, how do you know that well isn’t sitting on top of a volcano of oil, methane gas, etc.??? If it is, the psi is much larger than you think. Here is a link from National Geographic showing a asphalt volcano.”

Western Geco is one of several seismic companies shooting surveys in the GoM. A seismic survey consists of a ship pulling a bunch of streamers several miles behind it, then setting off air cannons. The sound waves travel through the water to the seafloor and deeper. Travel time for the sound waves to be reflected through the water and the earths surface and back is then analyzed. Sandstones are distinguished from shales, salts, dolomites, etc, etc, etc. Oil / gas / water can sometimes be distinguished as well. A volcano would be easily recognized with this highly technical technique. Salt domes stand out like a sore thumb…………

“18. The only sure way to remediate this problem is the relief well. Yes it will take some time to happen, but it will happen. Understand what the directional drillers are trying to do, basically hit a target in the earth the size of a dinner plate 18,000 feet away (3.4 miles). Not easy, but it can be done.

Enough for now as I’m sure this will spur additional questions……………….grey wolf

I don’t believe it can be done. It seems more like “You can do anything if you put your mind to it.””

Lets watch and see,

“What do the lessons learned from IXTOC 1 say for Deep Horizon?”

Can you say relief well. It appears as though operations have moved from solving the well problem to containment. There are two (2) high rate well testing vessels enroute to the MC 252.

“how did you come up with 30=1 as a formula 123×2200 = 270600 you missed the point your looking at water pressure per square inch im looking at what the presure of the oil pushing out could possibly be at …”

Hydrostatics are simple, see the earlier comment.

“grey wolf – the only time i’m aware of it being done was on a well that was several hundred feet deep .. and that took 9(??) months to accomplish!

is that the only example you can provide to back up your assertion that “it can be done”?”

Montara is the most recent case that comes to mind. Think of it this way, the typical blowout recovery for land wells is to move in Wild Well Control, Boots & Coots, or Red Adair. They would snuff the fire out (remove the oxygen) then cap the well with a series of valves. That method won’t work with wells in water, remember (ignition, source and oxygen) are required for fire. No O2 under water, so the industry had to come up with a different technique, hence the relief well…….Hopefully this explains it.

“Grey Wolf – what’s your comment, please, on where all the mud went that BP pumped into the well?

After all, this was a main point of SHR’s argument.

(PB statement: “Despite successfully pumping a total of over 30,000 barrels of heavy mud, in three attempts at rates of up to
80 barrels a minute, and deploying a wide range of different bridging materials, the operation did not overcome the flow from the well.”)”

This is an easy one. Recall the burst disks mentioned in earlier posts. They are there to prevent a buildup in pressure on the string of casing. Even though they had a couple of frac boats on location with the ability to pump at high rate, they had to be cognizant of the pressure on the casing and the burst disk. Don’t need to make things worse.

The other thing to consider is the velocity of the fluids traveling up the wellbore. I suspect they were very high, kind of like paddling upstream in the Nile river….Don’t really need to go in to any more depth.

“Exactly…they don’t need to use something on the scale of the Tsar Bomb. Just big enough to melt or fuse a few acres of material. Perhaps something with a yield of less than 1000 tons. We have very small nukes in our arsenal.”

I would hope we never get to this option.
[Very long response from SHR – too long for this posting, but read it if you’re interested]
SHR 6/13/2010 10:51 PM

Further Discussion on Technical Components of this Question at theOilDrum.com

The next day there were some relevant comments, I’ll list them here for now as they appeared in theOilDrum.com – BP’s Deepwater Oil Spill – the Problem of Cleaning Up Marshes – and Open Thread thread.

R2-3D on June 13, 2010 – 12:48pm Permalink | Subthread | Parent | Parent subthread | Comments top

Yes, with any blowout, you have the possibility of a parted casing string(s) downhole. Underground blowouts with burst casing are often related to shallow sands. After the well is controlled, you can run shallow (hi-resolution) seismic surveys (a series of single 2D lines at first) that will tell you where your subsurface hydrocarbons went. I’ve mentioned before I once sat on a relief well for an offshore blowout. The BOP stack was shut in (but it partially failed) but was shut in enough to cause the well to have a subsurface blowout. The gas flowed out the burst casing and along the outside of the whole thing and up to the surface. It also charged (flowed into) a shallow gas sand at about the same level as the burst casing. It was estimated later perhaps 3Bcfg flowed into the shallow sand in the vicinity of the blowout well. The blowout well “bridged over” before long. It most likely bridged over closest to the surface, as the gas quit flowing to the surface after a day or so, but since the shallow sand took maybe 3Bcf, the gas probably continued to flow into the shallow sand from the formations, up inside the casing and then through two strings of casing into the shallow sand.

Did the Top Kill give any information about a possible casing breach?
I’m pretty much out of my league when I talk about engineering casing designs; grab those salt grains as you read further.
With this Macondo 252 #1-01:
You have 36″ conductor(drive) pipe set to 320+ ft below mudline. Traditionally, these are driven down, banged on (it’s loud) until you can’t bang on them any more.
Next you have the 28″ casing (surface pipe) that is set in this case to around 1200′ +/- below mudline.
You then have the 22″ casing that is set about 2900′ +/- below mudline. I believe this is the pipe that most likely supports the bulk of the weight of the BOP stack.
The 18″ is a liner that’s hung off of the 22″ stack, I think. The base of the 18″ is nearly 4000′ below mudline. I don’t know where the top of the 18″ liner casing is, but let’s say 250′ above the base of the casing it was hung on, or about 2700′ below mudline.
Then the 16″ is run to the base of the BOP stack. The base of the 16″ is 6860′ below mudline.

If the formation fluids are coming up the outside of the 7 x 9 5/8″ tapered casing, they’re going up the inside of the 16″ casing.

So, let’s say that the fluids coming up the annulus between the 7 x 9 5/8″ tapered casing and the 16″ casing, and there’s somehow enough backpressure to burst through the casing. Let’s say it’s going through the 16″ casing. Most likely, it would not go through the 22″ AND the 28″ casing, but perhaps choose a spot lower than the base of the 28″ casing. (Why not go out deeper? It could. But bear with me) I seriously doubt it went out through the 16, 22, 28 and the 36 inch casing strings all at once within a few hundred feet of the surface.

So, I’m painting a scenario where the oil and gas “choose” a window to burst through. This assumes there’s enough backpressure to create that burst level pressure downhole. After all, if that “burst window” was that easy to pop through in the first place, the blowout would never have made it to the surface. Perhaps the riser keeling over created some temporary kinks before the riser kink itself breached. Who knows?

This all _assumes_ there _is_ a casing breach, something that’s merely speculated on. I’m trying to get to this description to make my own point.

What I’m suggesting is that _if_ there is a casing breach, it’s through the 16″ and the 22″ casing somewhere between 2700′ below mudline (or above whereever the 18″ liner is hanged from) and 1200′ below mudline (the base of the 28″ casing shoe) [Note: my emphasis]

If there’s anyone that asks you, “Why do they run electric logs all the way to the surface, you have a reason to tell them. Don’t you want to know if there are any sandy sections in that interval? I know I do.

Okay, we have a theoretical breach of two strings of casing between 2700′ below mudline and 1200′ below mudline in this scenario. Did the formation fluid get far, or did it seek the path of least resistance and travel up the outside of the casing/cement to the base of the BOP stack? Well, we might see blips and blobs of oil/gas or we might see a torrent.

NOW, let’s talk about the Top Kill. You have the BP engineers that already know what I’ve said to you. It’s a possibility. You deal with the reality. The reality is the bulk of the oil is coming up the BOP and into the riser. The Top Kill is tried after the new control pod is placed on the BOP stack. Pressures within the BOP stack are taken at various points before and after the Top Kill. I suspect the flow rates of mud and the pressures didn’t exactly match up, but that’s speculation on my part. What the effect of the Top Kill is, is to increase pressure at the surface, “bullheading” the formation fluids back down. The mud is pumped with enough volume to overcome the riser leaks. If you do this slowly, you don’t run a high risk of _causing_ a subsurface blowout, but if there is one already there, you could open that up and leak off into the shallow sands.

So, let’s say that some pressures and pumping mud volumes gave some BP engineers some indication that they’ve got a breach in the casing. They stop the Top Kill and proceed with capturing the oil as best they can (not so well so far, but whatever) in a passive manner.

Now to my point (whew, that was a long way to get here!)

The casing design means there’s little chance of the BOP stack falling over, or even moving five inches from its spot.

It also means there’s little chance for the BOP stack to fall off or completely break. What exactly is bent and at what angles are of interest. Did something bend enough below the BOP stack to break, and are we in danger of fluids coming out of somewhere really shallow? We don’t know. If fluids come out of a very shallow breach due to bending stresses, does that mean the well has failed? Far from it. The erosion you hear about is overrated. Formation sands can be made to erode, but there’s got to be a lot of them. Do you see that sand floating down in huge volumes? We saw the bullseye level the other day and that was not covered in all that much sand. We should see huge volumes of sand coating every bit of the BOP’s lower sections. We don’t. Sand production isn’t a big issue in this case at the moment. [Note: my emphasis]

Do any fluids going into our theoretical casing breach mean anything? Well, they’re obviously not coming up around the BOP stack in large volumes. Is the oil and gas leaving our breach and traveling laterally? Perhaps. What’s the mechanism? Have the fluids traveled seven miles away and only then popped up to the mudline to leak away? Now you have to calculate some volumes. What’s 7 miles times say 1800 feet wide times 20 feet high? Fill that volume with 5 ft of net oil, so instead of 20 feet high, it’s only 5 effective feet of oil ‘tall’. Maybe 3,000,000 barrels. Hey, anything is possible.

Point is, if the oil and gas DID leak through a casing breach, it’s meaningless to both the oil spill killing shore critters and relief wells.

Why does a casing breach not impact a relief well operation? Can’t the control mud flowing up the blowout from the relief well intersection just flow into the shallow formation forever, UTubing and preventing control of the blowout downhole? In theory, yes.

This is where the control fluids are added to the heavy mud, and this time it’s more than cellophane and nutshells. All you have to worry about is the top of the BOP stack. There needs to be some pushback ready to go. Those orifices are too big to control, but the theoretical casing breach 1800′ below the mudline is a problem, but it’s not an insurmountable problem.
cudBwrong on June 13, 2010 – 3:45pm Permalink | Subthread | Parent | Parent subthread | Comments top

R2: thanks for this detailed description.

The potential consequences of a casing breech depend upon the detailed circumstances.

One way to think about it is to imagine drilling a well from the bottom up. Suppose you had a rig down inside the reservoir, and you are drilling up towards the surface.

All of the material above the reservoir, the formations of rock, sand, sediment, and the seawater column, act like a huge column of drilling mud: they work to hold the reservoir in place.

If you drill up one foot, nothing is going to happen. The remaining materials will continue to hold the reservoir, as they have done for geologic periods of time.

If you drill all the way up to within a few feet of the sea floor, well, things might get interesting. The remaining overburden could give way, giving the reservoir a means of escaping into the water.

So the consequences very much depend upon the geology and pressures at and around the breech location.
R2-3D on June 13, 2010 – 4:56pm Permalink | Subthread | Parent | Parent subthread | Comments top

The Overshot Tool will be turned upside down over the entire area where the LMRP cap is now. Somehow, there will be a seal or two, or the entire thing will be lined with neoprene along the sides. How this seal functions we aren’t told, but we have been told they (BP engineers) expect to not worry about the seawater incursion. This means at least a decent seal, but probably a low leak off (this number will be critical, and it’s it’s not 1000# someone hasn’t designed this properly). (Again, I’m not an engineer, but part of the peanut gallery)

When the mud comes up from the relief well bottom kill, it will easily go past the BOP at the mudline and either
a) travel up the riser or whatever conducts the oil to the surface after the Overshot Tool is in place
b) the valve at the Overshot Tool connection will be closed.

This is that “backpressure” you have to have. How good the seal is between the Overshot Tool will be known that day. If there’s a small or no flow, all is working. What lost circulation material is used to seal any casing breach will also work in the seal at the Overshot Tool (however, I suspect that seal will be a dynamic one, and the effect of lost circulation material there will be fleeting.
R2-3D on June 13, 2010 – 3:46pm Permalink | Subthread | Parent | Parent subthread | Comments top

When it comes to mudline near the end of the Mississippi Delta, there’s no such thing as “consolidated”. You might get sand. You will get mud. You won’t get consolidated.

Let’s say there is a leak as I mentioned with the theoretical casing breach in this thread. If there isn’t significant volume of oil/gas, (and btw, I _would_ like to see gas bubbling up at the same leak as the oil, as in theory this would be the updip section of the casing breach and this is a gassy oil) then any oil under the mudline is oil that hasn’t entered the Gulf of Mexico. BP can’t even get fined for that. And unless there’s a significant flow to the surface, this is an academic exercise.

Edit to add: There’s zero guarantee that if there is that casing breach and what you see are whisps of oil from that casing breach, that this would be the spot to observe when the bottom kill proceeds. As I mentioned, when the bottom kill mud starts flowing up the annulus of the blowout, the theoretical casing breach will proven significant or insignificant/non-existent. That’s the time the ROV drivers earn their pay again, and when the lost circulation materials get applied in the well.

One thing is certain about the any theoretical casing breach: If the fluids can only reach the surface via a permeable layer, lost circulation material should stop it cold. If the fluids break through around the base of the BOP, then there’s a bigger issue, but it’s still something that can be dealt with.
ov on June 13, 2010 – 8:30pm Permalink | Subthread | Parent | Parent subthread | Comments top

I think they have cause for concern with that casing design, the 16″ being the weak spot with 6920 psi burst and nothing behind the casing but 14 ppg mud. I don’t think BP realized until the Top Kill burst the rupture disk that they were in communication with the annulus and that that was where the flow was coming from. In hindsight it was a good thing that the BOPs had failed as they did or total casing failure would have happened with no chance of any oil recovery while the relief wells were being drilled. So I would say that what caused the blowout was not having a casing design that could be shut in.

Since the flow was coming up the annulus any of the pressure and flow tests between drill pipe and kill line would only be testing the 7X9 7/8 and its seat in the downward direction. There was no lock down sleeve run. In the inquiry Mark said something about how the service rig would have to do that, I can’t remember him saying it was on the rig, but that it was in the drilling program and it hadn’t been run. Without the lockdown sleeve the only thing holding the seal in place is the weight of the casing, about 550,000 pounds. The seal goes from 9 7/8″ to 18″ though I don’t know how much of this would be exposed to the pressure at the bottom, it’s about 150 square inches and would only take a 3,700 psi pressure differential to lift the casing and break the seal. Also, with the weight of the casing off the bottom hole the pressure at the shoe might have been enough to start blowing the whole casing string to surface. What was cut off in the riser looks to me like 5 1/2″ drill pipe inside of 9 7/8″ casing.

I don’t think they had the order of the cement reversed. That would be just too huge a FU. But any cement will go through a period when it is setting up where it loses the hydrostatic pressure and will allow gas migration until the cement is fully set. Unless there were channels in the cement which is possibly since they ran 6 rather than the recommended 21 centralizers. In either case there might have been enough high pressure gas that migrated to the surface that it was enough to pop the seal at the wellhead.
Just Wondering on June 13, 2010 – 5:10pm Permalink | Subthread | Comments top

A lot of comment in this thread has speculated about the role of the “rupture/burst disks” in the failed well. The position of the three disks is highlighted in a published doc:


People have wondered whether or how one or more of these disks may have “failed”. But it’s not clear what the role of the these disks was supposed to be in the first place, other than “relieving pressure” in the most general sense. Also the word “failed” has a double meaning in connection with a one-use-only membrane-rupture device: does “failed” mean “ruptured as designed” or the opposite?

It would be good to understand the original purpose of the three 16-in. rupture/burst disks: why were they were placed in their respective locations and what they were supposed to do there? Here is info on the three disks, as presented in the document:

Top disk: At 6047 ft below surface of Gulf, hole in center for “wider” portion of drill pipe, must be a sliding fit to drill pipe, defines “top” of seawater fill region. What is above it? What is it isolating from what? A permanent installation or just temporary? Role in displacement operation?

Middle disk: At 8304 ft below surface, hole in center for “narrow” end of drill pipe, seems to define one end of column of “seawater” in annulus. But what is below it? Isn’t the seawater pumped down from the drill rig on the surface actually coming out at the bottom of the drill pipe? What then is the role of this rupture disk? Was it for “future use” after the displacement?

Bottom disk: At 9560 ft below the surface, no hole in center — a complete isolator between the seawater above and (presumably) the mud below (all the way to the bottom of the hole).

Can/does the drill pipe force its way through the center of these diaphragms as needed during drilling/cementing/logging operations? Do the top two disks normally “close up” behind a retreating drill pipe during a “trip out”? I’m assuming so (if the rupture disk installation is permanent). Are these disks permanently installed in the casing? Do they make a tight sliding fit with the drill pipe?

I can see these disks could rupture, from the bottom up, in a situation where a sufficiently large pressure differential built up between the reservoir and the upper portion of the well casing. So, in the case at hand, the bottom disk might have ruptured (as designed) during the blow-out. Is that a “failure”, or is it just something “unexpected”, in the situation leading up to the blow-out?

Okay, say the bottom disk is blown out. What difference could that have made during the “top kill”, or now? I can’t see how the other two disks could blow out, as the drill pipe was open to the surface.

Any insights greatly appreciated.


Too many of the key points raised by SHR do not seem very solid.

It appears also that the same master copy was used (based on looking at the copied HTML code) for both the godlikeproductions posting and theOildrum.com posting. Given that the intro/leadin to theOildrum posting was slightly different, and that dougr is a new user, and that he didn’t cite any other work/source for his posting, and that the way the links appeared in both documents most likely meant that someone used a straight text master copy then pasted it into the posting box in the blog/forums, my conclusion is that dougr and SHR are the same person.

Also, he used a few other aliases to try to drum up attention for his posting, in a fairly obvious way, on the oil drum, when it didn’t get the attention he had hoped it would get.

Also, when pushed, dougr was unable to demonstrate any further understanding or knowledge about the issues he was writing about, specifically about the disks performance. In other words, though he did some good research, his conclusions look weak.

In fact, the only thing I’d give in his favor is the otherwise inexplicable insistence by Matt Simons that the well is blown out sub-surface, and is spewing out oil from other locations. Unfortunately these statements have been quite inconsistent over the past few weeks, including some fairly absurd suggestions that the BOP itself is blown off the casing and is just sitting on the ocean floor, which is obviously isn’t, since it’s funneling out thousands of barrels a day of oil.

Simmons’ suggestion, likewise, that we nuke the well, is equally absurd, for many technical reasons (do we even have a nuclear device that can withstand about 12-13,000 pounds per square inch external pressure?) Since the gulf floor is made out of a thousand feet or more of mud, sort of, you’d have to lower the device, untested, undeveloped, and currently not existing, far down to have any hopes of success. And that success might become a horrible accident, spewing radiation or otherwise destabilizing matters even further. So that’s not likely to happen.

But I’m wondering, speaking only for myself, if there is some truth behind the otherwise apparently incoherent statements from Simmons that he has heard and for some reason is either accidentally or deliberately misrepresenting? Certainly the stock price of BP is being driven down, and his previous firm is buying up BP shares now while they are low, but that doesn’t seem in character with Matt Simmons, something else appears to be wrong with his thinking to be honest.

So my conclusion is that this is a tempting story, but it’s got too many holes in it that are too easily discovered to really be more than a decent internet story that someone is trying to launch for some reason, maybe because they believe it, I’d like to think that’s the case anyway. But I also believe that there is some nugget of truth to whatever Simmons especially has been talking about in terms of this blowout that for some reason he doesn’t have quite right. We shall see.

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