QUIZ / EXAM
TM5213 ADVANCED PRODUCTION ENGINEERING
PROGRAM STUDI MAGISTER PETROLEUM ENGINEERING
FACULTY OF MINING AND PETROLEUM ENGINEERING - ITB
SEMESTER II - 2019/2020
Dr. Amega Yasutra / Silvya Dewi Rahmawati, Ph.D.
Tuesday, 10 December 2024
Time 75 minute
Name: Haris Dewantoro
NIM: 22223002
I will work independently in the exam and I am ready to accept all the
consequences If I am proven cheating during exam.
Signature:
Read and choose True (T) of False (F) for the following questions.
(b)
(a)
(d)
(d) (e)
Figure 1. Pressure performance during unloading process
1. (1) Using Figure 1, the final stage of unloading process is represented using part (e). (T)
2. (1) Using Figure 1, when the gas enters the first valve is presented using part (b). (T)
3. (1) The objective of using gas lift is to decrease the liquid density and so reduce the flow
gradient in the tubing. (T)
4. (1) The more the gas is injected into the tubing, the more the liquid will be obtained in the
surface. (F)
5. (1) The disadvantage of using gas lift is very expensive of operational cost. (F)
6. (1) Gas lift operation is dependent of bottom hole temperature. (F)
7. (1) The intermittent gas lift applicable in either high‐BHP–low PI or low‐BHP–low PI reservoirs.
(T)
8. (1) Intermittent gas lift will form slug fluid flow type in the tubing, while continuous gas lift is
bubble type. (T)
Figure 2. Design of gas lift installations
9. (1) Using Figure 2, closed installations is suitable for continuous gas lift. (F)
10. (1) Chamber installations are used for accumulating liquid volume at bottom hole of
intermittent-flow gas lift wells. (T)
11. (1) Crooked/deviated holes present problem for gas lift injection. (F)
12. (1) Well depth is a limitation for gas lift installation. (F)
13. (1) The inflow period occurs when a sufficient volume of liquid has accumulated and gas is
injected through the operating valve to lift the slug to the surface. (T)
14. (1) There is a complex flowing gradient of the gas lifted liquids from the well. (T)
15. (1) Continuous Gas Lift production strategy will give huge advantage to be implemented for a
small fields with a small number of wells without compression requirement. (T)
16. (1) Operation of gas lift valves is affected by high produced solids. (F)
17. (1) Gas lift is efficient in terms of energy terms (typically 15-20%). (F)
18. (1) Shut-in well period on intermittent gas lift wells will depend on amount of available gas
injection. (T)
19. (1) Gas lifting of viscous crude < 15o API is easy and has high production efficiency. (T)
20. (1) Gradient of slug in intermittent gas lift well will be greater than gradient of gas injection.
(T)
21. (1) Gas injection allocation is implemented when the amount of available gas injection is greater
than the gas injection required. (T)
22. (1) The oil rates will decrease as the point of injection deepen. (T)
23. (1) Closed valve is determined by multiplication between dome pressure and bellows area.
(T)
24. (1) Test rack opening pressure is used to determine dome pressure at surface condition. (T)
25. (1) A Conventional Mandrel is when the valve is fitted into a lug on the outside of the mandrel.
(T)
26. (1) Plunger lift will automatically clean tubing of scale and paraffin (T).
27. (1) Plunger lift design requires calculation of average casing pressure. Average casing pressure is
calculated as a function of maximum casing pressure. (F)
28. (1) Echometer is a tool to determine working fluid level and static fluid level using sound wave
29. (1) Average oil column pressure is calculated using 𝑃𝑜𝑐 = 𝑔𝑜 𝑥 ℎ𝑜. (T)
given in the annulus surface (T)
30. (1) Plunger lift does not require electricity power. (T)
31. (1) Hydraulic pump is one of pump that work well for deviated well (T)
32. (1) ESP suits for well with sand problem (F)
33. (1) PCP works very well for High GOR wells (F)
34. (1) In PCP, the higher the viscosity, the higher the pressure loss (T)
35. (1) High fluid temperature becomes the main problem of ESP (T)
36. (1) Friction is a factor that increases fluid horse power in ESP compared to leakage (T)
37. (1) The higher the specific gravity liquid, the lower the ESP pump head pressure for a pump
with the same well depth (F)
38. (1) Floater pumps can be used to prevent abrasive material from entering the restricted area
of the ESP pump (T)
39. (1) Efficiency = work out/ work in (T)
40. (1) Plunger Lift can be used in both gas wells and oil wells (T)
41. (1) Plunger Lift cannot be used on wells that do not produce gas (T)
42. (1) The gas produced from the well with the Plunger lift is produced intermittently (T)
43. (1) Plunger Lift does not require electricity (T)
44. (1) PCP is the type of pump that has the highest lifting efficiency (T)
45. (1) PCP is very suitable for wells with strong water drive reservoir type and large PI values (T)
46. (1) Plunger Lift is suitable for wells with waxy fluid type (T)
47. (1) PCP cannot be used in wells that produce two phases, oil and gas (T)
48. (1) ESP is very suitable for wells with solution gas drive driving mechanism (F)
49. (1) SRP operating efficiency will be between range of 45 to 60 % (T).
50. (1) ESP is very good for paraffin handling (F).
