The saw blade is about 1/4 inch too small in diameter to fully cut through the choke/kill line stub… so the ROV is doing just like us, bending it back and forth to fatigue crack off the stub! Good video this evening of meaningful operations.
…bend bend bend… bend bend… he got it broken off.
Riser flange is in the way of the tool …needs to be 180 deg. Excellent video as you say.
[QUOTE=pumpjack hand;34725]When was the last time you worked on the floor? I don’t guess I’d be interested in working for a driller who couldn’t tell a company man to hold the line while he finished spacing out a tool joint for the shear ram, or at least finish the important task after he had politely hung up. I give this driller credit to do that.
There are certain things there’s always time to do, didn’t you say in an earlier post that you never cut corners when BOP safety is concerned?[/QUOTE]
I’m putting my coveralls on, heading to the rig floor right after I type this, how bout yourself?
[QUOTE=bnhpr;34733]I’m putting my coveralls on, heading to the rig floor right after I type this, how bout yourself?[/QUOTE]
I really don’t know what they think they’re doing… You absolutely can’t do this type of work without a crowbar and a sledge.
[QUOTE=bnhpr;34733]I’m putting my coveralls on, heading to the rig floor right after I type this, how bout yourself?[/QUOTE]
And I sincerely wish you the best of luck.
are those methane hydrate flakes dropping thru the ROV footage?
[QUOTE=bnhpr;34718]It sounds easy sitting here at the keyboard, but again, its not worked out in the real world. The driller has too much to do already.
Phone ringing off the hook, Company man, directional driller, toolhands, toolpusher and othe looky loo’s poking questions to him, not to mention, he is supervising 3-5 people all the time.
He needs a hand here from technology, and I suspect someday, he’ll have it.[/QUOTE]
I don’t know what rigs you have worked on… but it is done this way, and certainly on Transocean rigs (I worked one last year where this was the norm)… every time the driller trips in or out of the hole, a trip sheet is made up beforehand showing bit depth against stands of pipe run or pulled. It’s a simple matter to add an extra “column” showing tool joint positions in relation to the BOP rams.
I can send you a spreadsheet if you don’t believe this…
[QUOTE=Alf;34737]I don’t know what rigs you have worked on… but it is done this way, and certainly on Transocean rigs (I worked one last year where this was the norm)… every time the driller trips in or out of the hole, a trip sheet is made up beforehand showing bit depth against stands of pipe run or pulled. It’s a simple matter to add an extra “column” showing tool joint positions in relation to the BOP rams.
I can send you a spreadsheet if you don’t believe this…[/QUOTE]
Could things have been different in this instance? i.e. pretty much done with drilling/casing/cementing and just trying to move.
[QUOTE=bnhpr;34733]I’m putting my coveralls on, heading to the rig floor right after I type this, how bout yourself?[/QUOTE]
Sometimes I’m on the floor, sometimes I’m on the brake handle, sometimes I’m in the derrick, sometimes I’m in the library, sometimes I’m in the office, sometimes I’m in the welding shop, sometimes in the mechanic shop, sometimes I operate the winch, sometimes I’m on the design table, sometimes I need to be in more than one of those places at the same time, but I broke in on a standard triple on the floor at $5.40 an hour when they were already at 18,000’ drilling to 24,000’, and my point to you was, if a man is too distracted to do his job safely, shouldn’t we stop, look, and listen like we learned in 1st grade. Ain’t it 'bout time we got back to the basics…
[QUOTE=Alf;34737]I don’t know what rigs you have worked on… but it is done this way, and certainly on Transocean rigs (I worked one last year where this was the norm)… every time the driller trips in or out of the hole, a trip sheet is made up beforehand showing bit depth against stands of pipe run or pulled. It’s a simple matter to add an extra “column” showing tool joint positions in relation to the BOP rams.
I can send you a spreadsheet if you don’t believe this…[/QUOTE]
For specific operations, with the setting of plugs, tools, packers etc, detailed info is tracked in relation to position in the well and bop.
For the vast majority of drilling operations, a driller cannot tell you where each tool joint, stabiliser, motors, collars, hvwt and other non-shearables (250-500 tooljoints) is in relation to all the rams, annulars etc, 8 different positions in the stack at any point in time.
BS.
They have to stop and locate them…then verify against the paperwork.
When the bushings flew out of the well, and the TDS landed in the company mans office, do you think he turned around and looked at your spreadsheet?
Spreadsheets are what is killing this industry.
The driller needs a real time display, in cyberbase, that shows a tooljoint in relation to all his rams as they pass through the stack. This is achievable, it is something that drillers have asked for for years.
"When the bushings flew out of the well"
If you’re referring to the “bushing” it never was in the well…
Look. Can yall just stop it with the stupid dick measuring contest and get back to the tech discussion?
Real time monitoring would be great, BUT, it looks to me that their tool joint had been spaced correctly for circulating, does anyone come up with different numbers?
[QUOTE=Alf;34737]I don’t know what rigs you have worked on… but it is done this way, and certainly on Transocean rigs (I worked one last year where this was the norm)… every time the driller trips in or out of the hole, a trip sheet is made up beforehand showing bit depth against stands of pipe run or pulled. It’s a simple matter to add an extra “column” showing tool joint positions in relation to the BOP rams.
I can send you a spreadsheet if you don’t believe this…[/QUOTE]
Thanks Alf, I was sitting here scratching my head thinking, gee, how can a driller possibly not know critical information about his drill string, such as where to place it so to not grab on a joint, etc.? The answer is, he can’t not know. At least using a spreadsheet, and yeah, I could make one that would do it in about five minutes. That said, I’m surprised that the procedure isn’t somehow automated, and that the entire drilling procedure isn’t automated for safety, to increase productivity and to reduce labor costs. Certainly it will be soon, check this video out of an automated cpt pushing machine.
[QUOTE=bnhpr;34740]The driller needs a real time display, in cyberbase, that shows a tooljoint in relation to all his rams as they pass through the stack. This is achievable, it is something that drillers have asked for for years.[/QUOTE]
I’m taking what is good and leaving the rest here. I agree with this 100%. I’m very surprised that this automated real-time display isn’t already standard equipment, and people are still writing it down on forms in an aluminum clipboard.
And speaking of writing things down on a form in an aluminum clipboard. How are things like critical pressures, pump volumes, etc. recorded and displayed? Is the lack of proper display of this information a potential contributing factor to the blow out?
“and that the entire drilling procedure isn’t automated for safety, to increase productivity and to reduce labor costs.”
** on it since about 1930
Hearing video from Kenner La last Friday.
What jumped out at me during the testimony of the BP well design engineer was a question that Halliburton asked him. Halliburton designed the cement job on that last section of casing to have 21 centralizers. How many centralizers did BP use in that last section? His answer was 6. So, my question is wouldn’t a cement bond log have been particularly useful to have before displacing to sea water, since they had gone with so few centralizers?
[QUOTE=CPTdrillersails;34744]I’m taking what is good and leaving the rest here. I agree with this 100%. I’m very surprised that this automated real-time display isn’t already standard equipment, and people are still writing it down on forms in an aluminum clipboard.[/QUOTE]
Something as simple as a spring loaded calibrated wheel that could ride along the drill pipe could measure the length of the string. Height of hook from drill floor data strem also has possibilities of being used to feed data. Don’y know how far down they are calibrated. Plus or minus one foot should be close enough to determine the tool joint location. Thereafter use the weight indicator… that’s the old school way and proven way.
If we can use an ROV to cut riser in 5000 feet of water the drill string calculator display should be a breeze.
[QUOTE=lfgd521rc;34749]Something as simple as a spring loaded calibrated wheel that could ride along the drill pipe could measure the length of the string. Height of hook from drill floor data strem also has possibilities of being used to feed data. Don’y know how far down they are calibrated. Plus or minus one foot should be close enough to determine the tool joint location. Thereafter use the weight indicator… that’s the old school way and proven way.
If we can use an ROV to cut riser in 5000 feet of water the drill string calculator display should be a breeze.[/QUOTE]
We’ve looked at this, and most agree, the best place is in the lmrp, a mass indicator. The dwks motor(s) has an encoder, the cyberbase knows it’s posiiton, the mass indicator would see the tooljoint…the rest is programming.
That takes away stretch, heave, tides etc. This is my 3rd rig with AHD’s and when you throw it into active heave and see the line spooling in, and your not moving the blocks, it’s very decieving. It’s better if they cant see the drawworks.