Although the fracture network is a complex network of interconnected ribbons and threads, to simplify in the minds eye. Think of a permeable dividing wall between two different pressure chambers (reservoir and bottom of wellbore). We know the reservoir side is ~9000 psi and by calculation bottom of wellbore is approximately 5000 psi when top hole pressure is ~35 psi. This was the case prior to the winter shut in, so 4000 psi was attempting to diffuse through the wall. It largely failed, although it is important that there was some reservoir contact observed at one point as the wellbore pressure increased slightly indicating flow had occurred through the wall.
On the second attempt after the winter shut in, the plan was to reduce the 5000 psi at the bottom of the wellbore to say 3000 psi, so now there is 7000 psi trying to diffuse through the wall. A reasonable plan as 5000 psi had already proven its ability to pass a small quantity through.
Gas lift using nitrogen was the chosen method to achieve this, and it will have achieved the goal by lightening the liquid column in the well shaft. Adding light bubbles of gas displaces heavy liquids so reducing the total weight.
When a well is put on flow, the pressure to produce the flow comes from different sources as it progresses, and will transition over time.
Accumulated stored pressure, our starting point at 3000 psi top hole , which has come from slow evolution of gas from the reservoir over winter.
The stored gas on the well side of the wall will expand as the pressure drops because liquids/gas are being removed, so supporting flow. Also as pressure drops the walls of the reservoir relax inwards giving additional pressure support, this stage of flow does not require flow through the wall. After the accumulated pressure has gone it is only diffusion through the wall that maintains flow. We are there now.
It is still possible the 7000 psi will clear whatever is sealing the wall over time, but looking unlikely as the previous contact at 5000 psi has not re established, despite the higher 7000 psi.
Additionally as the flow rate reduces, so does the speed at which fluids/gases pass through the fractures leading to the bottom of the wellbore. Suggesting less resistance in that flow path and pointing back at the wall as the problem.
Swabbing and other forms of lightening the column would be pointless as gas lift has already tested, and is still testing the theory that increasing the pressure across the wall will increase flow .
What remains is what is sealing the wall, because we know the wall is permeable through the permeability testing of the IW1 cores, and we know there is oily gas at 9000 psi on the reservoir side.
It is my belief that the seal is created by the frack water acting on the reservoir and you don't have to frack with water. Diesel, propane, liquid Co2 have all been used elsewhere, but will add to the costs of fracking.
If the future of IW2 is to be a learner well for a future success, that is often the case in oil exploration and is not a waste, so much knowledge will have been acquired
Expand
Which in short is the fact that it may take a while to crack the code to unleash the oil from this field. I seem to recall that management had stated such a few years ago and it has been my long held belief. Having a gusher on first attempt is always the dream, and sometimes it happens. My focus was always on the probable reality that it will take a while to come up with the magic code which will unleash our liquid gold.... Patience and many irons in many fires. I'm so glad that we have such a talented management team working in this company. Make no mistake, management with their network of world class contacts are in the best position possible to achieve our goals.
(20min delay)