Page 25 - Acoustic Fluid Level Measurements

Index I-7

Petroleum Extension-The University of Texas at Austin
liquid level depression test. See also Walker test. reading acoustic record and, 3-6
beam-pumped wells, 7-8f recommendations for reducing, 2-3
to confirm annular gradient inversion, 8-10 to 8-13 non-upset tubing joints, 5-10
correlations for finding gradient and, 6-16 to 6-18 “N” type wave, 3-3
data points for, 6-10, 6-11f
to determine effective oil fraction, 6-17f, 6-19f obstructions, echoes generated by, 3-8
estimating gaseous column gradient and, 6-14f offshore platforms
for a gas well, 9-14 deviation in, 10-21 to 10-22
history of, 6-16 KB correction and, 2-1
during pressure buildup test, 7-6 random noises during acoustic tests, 10-4
pumping wells, 8-12f schematic and acoustic trace of, 9-15, 9-16f, 9-17f, 9-18f
liquid level echo, 2-3, 2-18, 2-27 subsurface safety valves in, 2-25
liquid level marker (LL), 2-28, 8-15 oil, gravity of, 6-20
liquid level survey oilfield facilities, hazards of, 4-12
automatic digital filtering for collar count and, 5-6 to 5-7, oil/water ratio, 6-24f
5-7f, 5-9t oil/water separation, 6-4
calculating acoustic velocity from gas, 5-10 to 5-13 one-dimensional wave equation, 3-15
collar count method, 5-2 to 5-4, 5-9t one-rate well test, 1-18 to 1-20, 1-20f
stepwise collar echo count, 5-4 operating conditions, changing for liquid level, 2-3
liquid loaded gas wells, 9-3, 9-25, 9-26f operating costs
liquid pump fillage, 8-5 acoustic fluid level measurements and, 3-1
liquid slugging, 2-33, 11-5 artificial lift efficiency and, 1-23
low-frequency waves, 4-1 energy supplied and, 1-2, 1-4
low-pass filter, 2-8 to 2-9, 2-18f, 2-29f, 5-3 gas lift wells, 11-1
low-pressure wells, 5-2, 5-10 overall efficiency and, 1-2
lubricator, plunger lift well, 11-2 operating procedures, acoustic fluid level survey, 4-13 to
4-19
mandrels. See gas lift mandrels. operating valve, 10-1
manual pulse generation, 4-5 to 4-6 oscillographic recordings, 4-2
microphones
history of, 4-2 to 4-3 packer in the gas lift well, 10-1
output of, 4-8 PAP plunger, 8-19, 8-20f
overview of, 4-10 to 4-11, 4-19 paraffin, 3-8, 8-13, 8-19 to 8-20, 8-21 to 8-22
sensitivity of, 4-18 to 4-19 particle velocity, 3-8, 3-12
in the typically operated gas gun, 4-6, 9-3 patents, oilfield applications, 4-2
mixture density, 6-18 PBHP. See producing bottomhole pressure (PBHP).
multi-phase flow, 6-9, 6-11 PC pump. See progressing cavity (PC) pump.
multi-rate flow test PDP. See pump discharge pressure (PDP).
inflow performance relation (IPR) and, 1-17 to 1-18, 1-17f, peak of the wave, 3-3
1-23f peak-to-peak amplitude, 3-2, 3-11, 3-22, 4-16, 5-4
monitored with acoustic fluid level records, 1-21 to 1-22, perforated zones, 8-7
1-21f, 1-22f perforations, 2-15, 2-15f, 2-16f, 6-2, 11-17
Phillips Natural Gas and Gasoline Department, 3-17
National Electrical Code (NEC), 4-12 PIP. See pump intake pressure (PIP).
National Fire Prevention Association, 4-12 pipe joint length, 5-15
National Institute for Petroleum and Energy Research plane wave, 3-3, 3-7 to 3-11, 3-7f, 3-23
(NIPER), 1-21 plunger lift wells
National Institute of Standards and Technology (NIST), 3-20 acoustic monitoring of, 11-6 to 11-7
natural gas separator, 8-5 anomalies in data, 11-13
needle-type valves, 2-3, 8-30, 9-4, 10-2, 10-4f data acquisition, 11-11 to 11-16, 11-12f
nitrogen gas, injecting to pressurize wellbore, 2-27, 4-15 determining appropriate cycle time, 11-1
noise. See also digital filters. determining plunger position and velocity, 11-6 to 11-8
background, 5-6, 5-15, 8-26, 10-2 to 10-3 field example, 11-20 to 11-21, 11-21f, 11-22f
gas flow, 4-18 gas properties, 11-16 to 11-17
high-frequency, 2-18, 2-25 monitoring of plunger position, 11-7f, 11-8 to 11-9, 11-8f,
obtaining second record because of, 2-2 11-10f, 11-11, 11-11f
pumping-related, 4-17, 4-17f operation cycle, 11-5 to 11-6, 11-6f
random, 4-16 to 4-17, 10-4, 10-6, 10-6f overview of, 11-1, 11-2f

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