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To complete a well is a whole different ballgame from drilling and setting casing. In this part of the world after casing is cemented the rig moves off and they wait several days for the cement to cure and then a completion rig is moved in. Over there they may have a sand line drum on the drilling rig to complete that well with, I don't know.
Completing a well is loading the hole with fluid to run a cement bond log, perforate the zone, swab the hole dry and normally breaking the zone with mud acid to clean it up and swabbing it back then frac. Good wells may clean themselves up after perforated.
If they complete with the drilling rig it will take a longer, imo.
How many million shares we gonna buy/sell before word gets out?? :)
I Don't know if Tarach-1 is a tight hole or not and cell phones are great unless there is no service for a hundred miles. Satellite communication is probably all they have.
My info normally came from service company hands that were on site for a short time but this will be a camp rig where everyone stays for most likely 28 days.
If they have set intermediate casing (and they should have by now) and are drilling/have drilled the lower section, they should have a very good idea on what's there.
Problem is I have no contacts there to find out anything..:(
Day 27 of drilling, if there wasn't a 5-6 day delay in reporting to us as they did in the JDZ, so they should be getting very close, imo..
Bob, I just checked in to see if Roger had done anything, sorry.
OT; lost a few shingles is all but a lot of damage just south of me.
WAG, maybe four times that. :)
They will have a good idea of what they have while drilling the zone/s. Mud loggers catch samples of the cuttings and check for florescence, odor and gas. They also draw up a drilling log that shows what they see and where it's at. At that point on a wild cat well they may want to run a drill stem test.
Time wise, I can't say from what little info we have.
Keep in mind they are drilling a big hole production well not a slim hole test well and it takes longer. My thought is they must be pretty sure of themselves..
His name is Mark St more or something like that, if I remember right.
With the top head drive and pumps SMP have on rig 106 and if they are running PDC bits, they should be getting real close to setting intermediate. imo.
Why would ERHC want to tight hole Tarach-1 when they have the whole block?
Wonder who? :)
After 11 years of buying and selling (a couple of times) ERHE on TDA they will no longer let me buy.
Yeah, and it produces a lot of oil & gas. I was talking about the first company that had it and drilled two wells. Been too long ago for me to remember who and all the details.
If I remember right they drilled two dry holes on highs at AKPO and walked away also.
Day 12, they should have surface set and be well on their way down by now.
I ask Dan how much surface they had to set and what size intermediate they were using, no reply.:(
They drilled the gas caps. You would have to go way back to get my thoughts. Here's two.
Edit, sorry OC I meant to reply to OldOil.
http://investorshub.advfn.com/boards/read_msg.aspx?message_id=64434259
http://investorshub.advfn.com/boards/read_msg.aspx?message_id=64399284
Oldoil,
most likely will not be anything to report for quiet a while. They have to drill and set 8,012 ft. of intermediate casing before they reach any pay zones imo. Normally intermediate is set just above any zones that could contain any high pressures and gives them something to nipple up BOP's on and also increase their mud weight to control any pressures encountered.
The last 1830 ft. is where we hope things get interesting.
You bet.. Just the type of rig and sub base it takes.
Yup, Tarach #2..:)
Thanks Gremlin
Guess the delay wasn't ERHC's fault..
The drilling comes in the back of a number of delays in arrival of equipment owned by Baker Hughes and Halliburton
Well, the "Google Master" is at it again. He just can't stand good news, lol.
About what I figure time wise. Lot of big hole to drill to set a 7" liner. Top head drive will help.
Mud loggers should have a pretty good picture off the samples also.
Nice on the trailer! :)
ERHC Energy Inc.: Drilling Commences in Kenya Block 11A
Tarach-1 well spuds
NAIROBI, KENYA, April 14, 2016 – ERHC Energy Kenya Ltd., the wholly owned Kenya-based subsidiary of ERHC Energy Inc. (OTC PINK:ERHE), today announced that its operating partner, CEPSA, has commenced drilling at the Tarach-1 well in Kenya Block 11A. ERHC is a publicly traded American company with oil and gas assets in Sub-Saharan Africa.
The Tarach-1 prospect's mean estimate of oil prospective unrisked resources is 66 million barrels. Mean unrisked prospective resources of all prospects and leads in Block 11A totals 662 million barrels. ERHC holds a 35 percent interest in Block 11A.
The Tarach-1 well is designed to drill from a 20-inch surface casing through intermediate casings down to 2,442 meters and set a 7-inch liner down to total depth (TD) of 3,000 meters. The prospect is defined by four 2D seismic lines out of the 2014 survey. The structural trap is a 3-way dip closure against a north-south normal fault plane at 1,426 mMD (-954m TVDSS) and covering a surface area of 12 sq.km. The vertical closure is calculated at 220 meters at the P10 closing contour.
ERHC Energy Kenya Ltd., headquartered in Nairobi, Kenya, is guided by General Manager Dr. Peter Thuo.
ERHC Energy Inc.: Drilling Commences in Kenya Block 11A
Tarach-1 well spuds
NAIROBI, KENYA, April 14, 2016 – ERHC Energy Kenya Ltd., the wholly owned Kenya-based subsidiary of ERHC Energy Inc. (OTC PINK:ERHE), today announced that its operating partner, CEPSA, has commenced drilling at the Tarach-1 well in Kenya Block 11A. ERHC is a publicly traded American company with oil and gas assets in Sub-Saharan Africa.
The Tarach-1 prospect's mean estimate of oil prospective unrisked resources is 66 million barrels. Mean unrisked prospective resources of all prospects and leads in Block 11A totals 662 million barrels. ERHC holds a 35 percent interest in Block 11A.
The Tarach-1 well is designed to drill from a 20-inch surface casing through intermediate casings down to 2,442 meters and set a 7-inch liner down to total depth (TD) of 3,000 meters. The prospect is defined by four 2D seismic lines out of the 2014 survey. The structural trap is a 3-way dip closure against a north-south normal fault plane at 1,426 mMD (-954m TVDSS) and covering a surface area of 12 sq.km. The vertical closure is calculated at 220 meters at the P10 closing contour.
ERHC Energy Kenya Ltd., headquartered in Nairobi, Kenya, is guided by General Manager Dr. Peter Thuo.
I have not heard of that one either..
You made the same mistake I did J. Type of rig is drilling. Ck it out.
Yup, but we always had to be drilling before anything like that showed up. Some things can't be tested in yard.
edit, That picture of 106 shows pipe in the derrick so it has drilled, imo.
Some times bad luck when new components fail. Had it happen on a new 22k ft electric we built. SCR house failed, burnt up four 800 hp traction motors and hung us in the hole. We got all that fixed and spotted oil to free pipe and the weight indicator failed. I pulled the drill pipe into, lol.
Yeah, could be the rigs first hole and needs the bugs worked out. Never thought of that.
Rig 105 shows same thing except status is drilling.
Maybe both are new rigs.
http://www.smp-drilling.com/media/fiches/smp-en-tech-data-sheet-smp105.pdf
SMP's website still list rig 106 as available instead of active.
Maybe because of just one well or slow update but looks like if they were drilling it would be listed as active.
http://www.smp-drilling.com/rigs.html
All according to who you are drilling for..
And, it certainly does happen..
Yup, been there, done that many times. On production also.
ERHC will never pay a dime to the drilling company directly. CEPSA is the operator. CEPSA pays the driller and ERHC pays CEPSA.
Correct and a lot better than the "Joint Interest Billing" you stated.
I wasn't going to say anything about this but now I will.
Quote,
Typically costs are paid as you go on a monthly basis. They are usually billed on a statement called a joint interest billing(JIB) which details all the costs for the prior month.
So you are saying that the drilling company will pay out 10's of thousands of dollars to move the rig, rig up and drill for up to thirty days and then bill ERHC for their 35%??
The operator (CEPSA) has most likely already collected most if not all drilling cost from working interest owners.
If oil is found then completion cost will be owed, imo.
Normally an estimate of moving and drilling cost is paid when contract is signed. The operator will be billed for any cost overrun. jmo.
Maybe Try can get us a set of well logs on Tarach-1 like he did on OBO.. :)
Very strange that they would take Midland Tx off the website but leave this??
Midland Power Station
The Midland Power Station (MPS) was a project conceived and developed by Cirque Energy, LLC. The MPS was to provide all of the steam requirements and nearly of the electrical energy required for the Dow Corning Corporation Midland Plant Site in Midland, Michigan.
OC, drilling water is the only thing I can think of that may delay drilling. But, normally the small rig that drills and sets conductor drills a water well and cases it. Rig hands will drop in a pump and run it off generators on the rig. They also use it in completion and then leave it for locals. Just a thought.
Didn't take this off website..
Deployable Gasification Units (DGUs)
Cirque Energy, in conjunction with Northrop Grumman Corporation have jointly developed a Deployable Gasification Unit (DGU) for sale to military, government, industrial and commercial customers. The DGUs utililize Cirque Energy's gasification and syngas condition technology, couple with conventional reciprocating engine generator technology. Any carbon-based waste stream (MSW, biomass, etc) of approximately 2-10 tons per day can be cleanly and efficiently turned into combined heat and power (CHP) energy.
Gremlin, if the rig is up and on location, they are drilling!
No one rigs up and then sends the hands home.. Why would they?
Most likely a camp rig where all crews are on location until well is finished. The rig hands are the ones that put the rig together and raises it, not the rig movers.
They should have spud by now according to the timelines on this statement.
The rig should be available from early- or mid-May (at the latest), depending on the well results.
The top head drive makes it a faster rig overall but there is still a lot of time in drilling and setting pipe on a well like this. If any DST's or wall cores are run, it'll take longer.
Sure don't understand why PN is so tight lipped..