"
.. note the word 'digital' ... then note the words'volume'&'required'... now go hit that keyword and seacrh ... sigh"
1.5-2ml depending on brand used.. Conventional method 140-600ml, little glass tubie thing bobbing round like a cork..
What's the point of all this? Are you saying they could have taken a sample so why didn't they?
Now if you are going back to confirm something you encountered earlier on a drilling expedition, may I ask what have you previously done?.. You sampled the bloody thing yeah?
But as Flam states & quite rightly, if it wasn't to the agreed (ASX) standard of test or the certifier isn't happy with the procedure used (Digi meter or not!) then you cannot report the value can you? No you cannot. Below is AP, your guy and our man with the plan who states back in December that;
SYDNEY, AUSTRALIA (18 DECEMBER 2023)
Melbana Energy’s Executive Chairman, Andrew Purcell, commented: “It’s always exciting when the drill bit starts spinning again, particularly when you know what you’re going to encounter. The team is in good spirits, the weather is mild (save for some late afternoon thunderstorms that would even impress a Queenslander) and we’re underway with a fit for purpose appraisal program designed for the known subsurface conditions.
We are looking forward
to confirming the oil quality, production rates and reservoir properties
of the two deeper reservoirs we encountered there last year.
The best-case outcome is one that would give us two vertically stacked and geologically independent productive reservoirs
to add to the several productive units that we have already established exist in the Amistad reservoir above.
We are planning to flow test Unit 3 of the shallow Amistad reservoir in late January, following which we’ll quickly be into the
Alameda reservoir then the
Marti reservoir, both of which
gave energetic influx of hydrocarbons into the well bore last time.
If drilling goes according to plan(hopefully better, like it did in Alameda-2, given this is also a well designed for the conditions) we will be doing
our first flow test in March.
We’re also targeting February for the release of the independent resource certifier’s assessment of our reworked volumes for parts of the Amistad-1 reservoir, which we are looking forward to seeing
given the significant increase in net pay interval combined with lighter oil than what was assumed in the previous assessment.
What am I doing holding, why I'm punting on the outcome LB.. What does it look like?
Why don't yopu invest in an area of expertise LB?
Or would you much rather play devils advocate by pointing out some completions scenarios to other poor unfortunates who have been sucked in by the ramp crowd.?
Ramping you say, like promoting West Wits as a Big Gold Mine once it gets going? Why on earth do you think GT sold out his entire holding?
But enough about African Gold Mines and undiscovered IOCG's.. Tell me, just how do they determine all the characteristics of a Naturally Fractured Carbonate Reservoir.. It seems awfully complex
To date, over 1,500 barrels of oil have flowed naturally to surface during the testing program and the resultant production trucked to a nearby oil tank battery (Figure 4).
The Unit 1B section was completed for future production, whilst Units 1A and 3 were suspended for potential future development and production.
Alameda-2 early productionEarly production from Unit 1B at Alameda-2 was completed in the quarter. Production testing was
run for a total of ten (10) days, twice the total duration of the Drill Stem Test conducted in this unit
previously, resulting in 20 tanker loads of oil being produced and delivered to offsite storage.
The flow peaked at 1,183 barrels of oil per day (BOPD) and was intentionally choked back to ensure
a constant rate for the test period to optimise the collection of reservoir data.
The extended period of production also provided important performance data on logistical
arrangements for the transport and storage of the oil produced.
The produced oil was sampled for Pressure Volume and Temperature (PVT) analysis and other data
obtained were of good quality were analysed by the Company’s geoscience team and consultants.
The well was shut in to gain further valuable data on the reservoir’s characteristics by monitoring the
build-up of pressure in the well.
The conclusions drawn from this analysis have been important factors in the refinement of the
development plan, including well design and spacing, for this upper sheet reservoir.
Now we are all fully aware of the 293 BOPD figure LB.. I do not disagree with it at all, but I'll wager the flow is not linear Sir..
Note the 12/64" choke equates to 293 barrels as stated (Deliberately set by the company for testing purposes)
293/12 = 24.4 barrels per fractional increment measured in 64'ths
Now if that figure were linear then the choke sizes stated would correspond to 586 BOPD at 24/64", 732 at 30/64"
& finally 976 BOPD at 40/64" which was the largest size mentioned.
I'll take 976 BOPD unassisted light/heavy sweet crude at surface as a good place to start any day..
But if you have a look at what else was reported it says that the peak in the test achieved in the Dec qtrly was 1183 which you would think had to come from the largest choke size and that was 30/64" because that is the size it "ranged up to"
1183/30 equals 39.4 BOPD per increment and the max peak achieved (assumed to be from the max choke size mentioned of 40/64" was 1903 BOPD which is an astounding 47.6 BOPD per fractional increment.
It would appear, at least to this uneducated O&G layman that the pressure gradient curve is far from linear which to me seems reasonable.
Sometimes ignorance is bliss, don't they say.. Unless of course you are invested in a spec play in the market... ,? ;-)
"The Unit 1B section was
completed for future production," ref Sep Qtrly
You'll know this one surely, what does "Completed" mean in relation to a well?
AP & MAY have been performing far above expectations operationally.
gltah h8tey
(20min delay)
