API St 65-2:2010 pdf download

API St 65-2:2010 pdf download.lsolating Potential Flow Zones During Well Construction.
3.1.40
non-aqueous fluid
NAF
Non-aqueous fluid is a non-aqueous drilling fluid or well circulating fluid. Common NAF systems are diesel, mineral oil, or synthetic fluid based invert emulsions, or other non-water based fluids.
3.1.41
nippling down
The process of removing well-control or pressure-control equipment such as a BOP system.
3.1.42
nippling up
The process of installing well-control or pressure-control equipment such as a BOP system.
3.1.43
operator imposed casing pressure
Pressure in a casing that is operator imposed for purposes such as casing pressure integrity tests (prior to drilling out the shoe), gas lift, fluid injection, stimulation treatments, thermal insulation, etc.
3.1.44
overbalance pressure
OBP
Overbalance pressure is the amount by which the hydrostatic pressure exceeds the pore pressure of a formation.
3.1.45
physical barrier element
Physical barrier elements can be classified as hydrostatic, mechanical or solidified chemical materials (usually cement).
3.1.46
polished bore receptacle
PBR
A device with a honed internal diameter (ID) sealing surface for landing a production tubing seal assembly or tie back casing.
3.1.47
pore pressure
PP
Pore pressure is the pressure of the fluid inside the pore spaces of a formation.
3.1.48
potential flow zone
Any zone in a well where flow is possible under when wellbore pressure is less than pore pressure.
3.1.49
production casing
Casing that is set through a productive interval.
3.1.50
production liner
A liner that is set through a productive interval.
3.1.51
production riser
The casing string(s) rising from the seafloor to the wellhead on fixed platforms or the casing string(s) attached to the subsea wellhead rising from the seafloor to the surface wellhead on hybrid wells.
3.1.52
production tubing
Tubing that is run inside the production casing and used to convey produced fluids from the hydrocarbon bearing formation to the surface. Tubing may also be used for injection.
3.1.53
pressure while drilling
PWD
The measurement of downhole pressure while drilling by a tool installed in the BHA.
3.1.54
rate of penetration
ROP
Common term for drilling rate; usually expressed in units of ft/hour or rn/hour.
3.1.55
static gel strength
SGS
The yield stress of fluids at rest.
3.1.56
structural pipe (or casing)
Pipe utilized to facilitate the drilling of a well, but not intended for pressure containment after the well has been drilled. Supports unconsolidated sediments and provides hole stability for initial drilling operations, axial support for casing loads and bending loads from the wellhead. See also definition for drive/jet pipe.
3.1.57
subsea wells
Wells drilled and completed with a subsea wellhead located near the seafloor.
3.1.58
subsea wellhead
A wellhead that is located near the seafloor.
3.1.59
surface casing
Casing run to isolate shallow formations.
3.1.60
surface well
A land or offshore well completed on the surface with individual casing heads, tubing head, a surface tubing hanger, and a surface christmas tree, all residing at a designated level above the water line on a fixed platform.
3.1.61
sustained casing pressure
scP
Pressure in an annulus of casing strings that is measurable at the welihead that rebuilds to at least the same pressure level after pressure has been bled down. SCP is not due solely to temperature induced fluid expansion or a pressure that has been imposed by the operator. See API RP 90 for further information.