With the depths at which the stimulations were initiated now available (128 gross feet starting at 10957 and finishing at 11087 ft ) It becomes very interesting to compare against other facts we know
The HRZ depth is 10963 to 11165 ft, 202 gross feet, so its clear the stimulation begins at the top of the HRZ and includes a few feet of the Hue
88e executed two seperate stimulations, upper and lower, with the original intent that they would not be in communication. So reasonable to pressume there was a buffer zone planned, over which no perforations in the wellbore would be created. Its height will have to be a guess, but 50 feet seems reasonable. Leaving 78 feet of well bore over which perforations have been created, divide that into upper and lower sections (say equally but we dont know) gives 39 feet each. As the frack fluid is introduced to the reservoir through the perforations fracturing takes place, both at 90 degrees to the well bore and to a lesser length vertically. As can be demonstrated by the now established communication between upper and lower zone stimulations.
What now stands out is the lower stimulations lowest point at 11087 is 48 feet above the strata that produced the photographed oil samples (11135 to 11150 ft).
88e has the best minds in the business working on this, and this is their plan based on a comprehensive data set. We can conclude the fracture will also be accessing this zone, via the fracture network created, but chose not to access it directly for good reason. Speculating but less brittle zones will not propagate a fracture well, and will be less stable which could be the reason to avoid direct contact. I am sure it will come, it just has some extra feet to travel through the horizontal fractures to get there.
Back to the flow testing RNS, Some have expressed concern at the drop in well head pressure from 3500 psi to 1130 psi. To have flow a pressure drop must be created, so it is a given that the 3500 had to lower. For 88e to use the wording " maintain pressure"implies holding the pressure at ~ 1130 by reducing the flow to 70 bpd, and also implies ~2400 psi is the differential pressure they want at this stage of the flow back.
The rise in pressure at the well head on the first hint of kick does not mean the reservoir is producing more pressure. Reservoir pressure is fixed at the pore pressure mother nature created (~8500 psi),
what changed is the hydrostatic head lowered due to displacement of water with lighter hydrocarbons. Then more of the available 8500 psi will show at the well head, in the extreme and impossible, if there was no hydrostatic head, the well head would show 8500 psi.
http://www.asx.com.au/asxpdf/20160411/pdf/436ffv24ksdkgp.pdf
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http://www.asx.com.au/asxpdf/20160210/pdf/434ykmv6t34wl0.pdf
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