1. Chapter 3 ROD PUMPS PTRT 2432 – 01 Vern Wilson
ARTIFICIAL LIFT
Chapter 3
ROD PUMPS
PTRT 2432 – 01
Vern Wilson

2. Barnett Shale Production

3. Baby Pumping Unit - Luling

4. Setting Sun

5. Lufkin Mark II

6. Typical Pumping Tree

7. Typical Clean Pumping Tree

9. Objectives Sucker rod operation Beam pumping unit Counterbalance
Fluid pounding
Gas locking
Pneumatic pump
PCP
Advantages

10. Pumping Unit

11. Large Pumping Unit

12. COMPLETE SYSTEM Perfs and reservroir PSN and BHP Pull tube to rods
Stuffing box
Flow Tee – flow line and chemicals
Polish Rod
Bridle, hangar and clamp
Horsehead to walking beam to Pitman Arms to Crank Arms
Gear Box and Torque
Power

14. Geometry

15. Stuffing Box

16. Stuffing Box

17. Double Stuffing Box Click on next slide Click on Animations
Click on Preview

19. Plungers

20. Balls and Seats

21. Cages

22. Barrels

23. Polish Rod Clamps

24. Bridle, Clamp and Horsehead

25. Hold Down Seal Assemblies

26. Sucker Rod Guides

27. Hollow Rod

28. Wyoming Oilfield

29. Travis Peak Pumper East TX

30. Comparison Pics

31. East Texas Oilfield

32. OTHER UNITS Pneumatic Units – Power cylinders lift rods
Hydraulic Units – Long 20 foot strokes
Cable wind Units – 20 to 80 foot stroke lengths

33. Advantages of Rod Systems
1) Very common
2) Wide range of applications
3) Reliable
4) Easy to analyze
5) Hi Temp or viscous oil can be pumped
6) Treating is easy
7) Various power sources
8) High salvage value

34. Disadvantages of Rod Systems
1) No good in crooked holes
2) Depth and volume limitations
3) High GOR or high paraffin causes problems
4) High profile
5) Heavy weight for offshore use
6) Pulling unit not always available

35. WELL TEST Single phase flow – direct pressure relationship Drawdown –
Production = PI (Pr – Pwf) = Barrels per day
PI = Bbls/day/psi – constant
PI = Bbls per day / (Pr – Pwf)
Example:
PI = 200 BOPD / (4000 – 3000) = 0.2 bbl/day/psi
Therefore at 1000 psi Pwf the flow would be 600 BOPD

36. ADVANTAGES Most common Wide range – oil to gas
Produce to depletion – BACK PRESSURE VALVES
Reliable
Relatively easy to analyze
Hi or Lo API
Hi or Lo Temp
Electricity or gas driven

37. DISADVANTAGES Not suitable for crooked holes – roller rods etc.
High GOR
Sand
Paraffin
Unsightly
Weight - especially offshore
Requires a pulling unit

38. Back Pressure Valves

39. Fluid Level Video

40. Dynamometer Surface Unit

41. Dynamometers
Downhole

42. Gear Box

43. Gear Box

44. Gear Box through inspection plate
Herringbone Gears – Double Reduction

45. Gear Box
Single Reduction

46. Dynamometer Read Out

47. Before and After

48. Mark II

49. Power Sources for Pump Jacks

50. Gas Compressors – Beam mount

51. Heavy Duty Rod w/ Dynamometer

52. Hybrid PU

53. Dongying Dayang – Belt Unit
Max T = 53
Max L = 30’
Max SPM = 4

54. Hybrid PU
The advantages of a pumping unit with a slow long stroke with constant rod velocity for pumping deep, troublesome, high volume and heavy oil wells are well known. The proven reliability in the basic design principle of the Dura-Lift system means less wear on pumps, rod strings and tubing.

55. Hybrid Base Unit

56. Brush and Seal Hold Down
Can release a friction hold down by preventing sand to stick it in place in the PSN

58. PROGRESSIVE CAVITY PUMPS

59. Progressive Cavity - PCP
ROTOR
Chrome plated steel external helix
STATOR
Synthetic elastomer

60. PCP Driver – Stamper - Luling

61. PCP Driver

62. PCP Motor and Driver

63. PCP Pump

64. w

65. PCP Installation
In a typical installation, the rotor is connected to the rod string, while the stator is run on the end of the production tubing
The eccentric rotation of the rotor within the stator causes a series of sealed cavities to form. These cavities move progressively from the suction end to the discharge end of the pump body. As each cavity diminishes in size, another increases in size at the same rate.
the total cross-sectional area of the cavities is constant. This results in a continuous, non-pulsating, positive displacement of fluid.

66. Formation Sand from PCP Well

67. PCP Advantages 1) Low power cost 2) Pumps high viscous fluids
3) Can handle sand
4) Low profile
Disadvantages:
1) Limited to 4000 feet
2) 400 BTFPD max
3) Not well known

68. Luling Pumping Unit

69. Pumping in Wyoming

70. East Texas Pumping Unit

71. East Texas

72. Homework
Submit Self Test Chapter 4 Page 48