Page 10 - Petroleum Production Engineering, A Computer-Assisted Approach

Guo, Boyun / Petroleum Production Engineering, A Computer-Assisted Approach Guo-prelims Final Proof page xviii 29.12.2006 10:39am

xviii LIST OF FIGURES

Figure 10.5: A typical spherical low-pressure Figure 12.10: Pump dynagraph cards: (a) ideal card,
separator. (b) gas compression on down-stroke,
Figure 10.6: Water content of natural gases. (c) gas expansion on upstroke, (d) fluid
Figure 10.7: Flow diagram of a typical solid desiccant pound, (e) vibration due to fluid pound,
dehydration plant. (f) gas lock.
Figure 10.8: Flow diagram of a typical glycol Figure 12.11: Surface Dynamometer Card: (a) ideal
dehydrator. card (stretch and contraction), (b) ideal
Figure 10.9: Gas capacity of vertical inlet scrubbers card (acceleration), (c) three typical
based on 0.7-specific gravity at 100 8F. cards.
Figure 10.10: Gas capacity for trayed glycol contactors Figure 12.12: Strain-gage–type dynamometer chart.
based on 0.7-specific gravity at 100 8F. Figure 12.13: Surface to down hole cards derived from
Figure 10.11: Gas capacity for packed glycol surface dynamometer card.
contactors based on 0.7-specific gravity Figure 13.1: Configuration of a typical gas lift well.
at 100 8F. Figure 13.2: A simplified flow diagram of a closed
Figure 10.12: The required minimum height of packing rotary gas lift system for single
of a packed contactor, or the minimum intermittent well.
number of trays of a trayed contactor. Figure 13.3: A sketch of continuous gas lift.
Figure 11.1: Double-action stroke in a duplex pump. Figure 13.4: Pressure relationship in a continuous gas
Figure 11.2: Single-action stroke in a triplex pump. lift.
Figure 11.3: Elements of a typical reciprocating Figure 13.5: System analysis plot given by GasLift
compressor. Potential.xls for the unlimited gas
Figure 11.4: Cross-section of a centrifugal injection case.
compressor. Figure 13.6: System analysis plot given by GasLift
Figure 11.5: Basic pressure–volume diagram. Potential.xls for the limited gas injection
Figure 11.6: Flow diagram of a two-stage case.
compression unit. Figure 13.7: Well unloading sequence.
Figure 11.7: Fuel consumption of prime movers using Figure 13.8: Flow characteristics of orifice-type
three types of fuel. valves.
Figure 11.8: Fuel consumption of prime movers using Figure 13.9: Unbalanced bellow valve at its closed
natural gas as fuel. condition.
Figure 11.9: Effect of elevation on prime mover Figure 13.10: Unbalanced bellow valve at its open
power. condition.
Figure 11.10: Darcy–Wiesbach friction factor chart. Figure 13.11: Flow characteristics of unbalanced valves.
Figure 11.11: Stresses generated by internal pressure p Figure 13.12: A sketch of a balanced pressure valve.
in a thin-wall pipe, D=t > 20. Figure 13.13: A sketch of a pilot valve.
Figure 11.12: Stresses generated by internal pressure p Figure 13.14: A sketch of a throttling pressure valve.
in a thick-wall pipe, D=t < 20. Figure 13.15: A sketch of a fluid-operated valve.
Figure 11.13: Calculated temperature profiles with a Figure 13.16: A sketch of a differential valve.
polyethylene layer of 0.0254 M (1 in.). Figure 13.17: A sketch of combination valve.
Figure 11.14: Calculated steady-flow temperature Figure 13.18: A flow diagram to illustrate procedure of
profiles with polyethylene layers of valve spacing.
various thicknesses. Figure 13.19: Illustrative plot of BHP of an
Figure 11.15: Calculated temperature profiles with a intermittent flow.
polypropylene layer of 0.0254 M (1 in.). Figure 13.20: Intermittent flow gradient at mid-point
Figure 11.16: Calculated steady-flow temperature of tubing.
profiles with polypropylene layers of Figure 13.21: Example Problem 13.8 schematic and
various thicknesses. BHP build.up for slug flow.
Figure 11.17: Calculated temperature profiles with a Figure 13.22: Three types of gas lift installations.
polyurethane layer of 0.0254 M (1 in.). Figure 13.23: Sketch of a standard two-packer
Figure 11.18: Calculated steady-flow temperature chamber.
profiles with polyurethane layers of four Figure 13.24: A sketch of an insert chamber.
thicknesses. Figure 13.25: A sketch of a reserve flow chamber.
Figure 12.1: A diagrammatic drawing of a sucker rod Figure 14.1: A sketch of an ESP installation.
pumping system. Figure 14.2: An internal schematic of centrifugal
Figure 12.2: Sketch of three types of pumping units: pump.
(a) conventional unit; (b) Lufkin Mark II Figure 14.3: A sketch of a multistage centrifugal
unit; (c) air-balanced unit. pump.
Figure 12.3: The pumping cycle: (a) plunger moving Figure 14.4: A typical ESP characteristic chart.
down, near the bottom of the stroke; Figure 14.5: A sketch of a hydraulic piston pump.
(b) plunger moving up, near the bottom Figure 14.6: Sketch of a PCP system.
of the stroke; (c) plunger moving up, Figure 14.7: Rotor and stator geometry of PCP.
near the top of the stroke; (d) plunger Figure 14.8: Four flow regimes commonly
moving down, near the top of the stroke. encountered in gas wells.
Figure 12.4: Two types of plunger pumps. Figure 14.9: A sketch of a plunger lift system.
Figure 12.5: Polished rod motion for (a) conventional Figure 14.10: Sketch of a hydraulic jet pump
pumping unit and (b) air-balanced unit. installation.
Figure 12.6: Definitions of conventional pumping Figure 14.11: Working principle of a hydraulic jet
unit API geometry dimensions. pump.
Figure 12.7: Approximate motion of connection point Figure 14.12: Example jet pump performance chart.
between pitman arm and walking beam. Figure 15.1: Temperature and spinner flowmeter-
Figure 12.8: Sucker rod pumping unit selection chart. derived production profile.
Figure 12.9: A sketch of pump dynagraph. Figure 15.2: Notations for a horizontal wellbore.