The true test here will be the post frac results in the lateral. Considering the low perm in this section, I doubt if operator will be looking to sit on the formation for extended periods to get a true bottom hole pressure as well as fluid samples - too high a possibility of getting the testing tool stuck (even if they are in oil based drilling fluid).
It is possible that operator is doing a "DFIT" test to get an idea of frac gradients and permeability.
Regardless of what they are doing, the next step should be to plug back and start to drill curve for horizontal wellbore.
How do we know this area is low perm and what does this mean. thanks
Low permeability. The other primary factor for a reservoir is porosity. Porosity is the size of the pores between the grains of rock which determines the volume of hydrocarbons the formation can hold. Permeability is a measure of how connected the pore spaces are to each other which determines whether hydrocarbons can migrate through the rock matrix to a wellbore. Low perm formations require horizontal wellbores and hydraulic fracturing in order to contact as much of the hydrocarbon bearing zone as possible and to fracture the formation to increase permeability so that the hydrocarbons can flow to the welbore.
Friday, 12/14, the rig reported 59 days Drilling Ahead @ 16,481'.
Skip, what was the progress / depth reported as of 12/7 (last week)? Looking at progress drilling in curve and lateral over past week.
Last Friday, 14,214'.
2200' progress in a week - assuming 1-2 trips at least in there to change bottom hole assemblies. Next Friday's report should show some significant progress.
But I won't predict how much! LOL
Skip - thanks for that update
12/21, 66 days Drilling Ahead @ 19,161'.
REPORT DATEWELL STATUSMEASURED DEPTHTRUE VERT DEPTHDETAIL12/26/20180519161DRLD LATERAL F/ 18569' TO 19161'; ENCOUNTERED LOSSES @ 19161'; CURED LOSSED
Rock Man, what are “losses” and how are they cured?
Putting reply to Plainsman here - no reply option left under his post @ "losses"
"Losses" is basically losing a significant part of the drilling mud / fluid that is in the wellbore to the formation (e.g. into fractures). When this happens, the hydrostatic pressure that this drilling fluid creates to control the well from flowing material (O&G&Water) to surface is decreased.
Worst case scenario is total blow out.
"Losses" are controlled in many ways but usually by pumping lost circulation material (LCM) to try to "seal" the wellbore and stop the fluid losses.
For old times, it is like pumping Bar's Leak in a car radiator to seal off leaks in the system.
12/28 73 days drilling ahead @ 19,161'.
no progress this past week / looks like the lost circulation that was encountered was pretty severe.