GATE Petroleum Engineering Petroleum Production Operations Syllabus

Petroleum Production Operations syllabus — full chapter and topic list

Expand any chapter to see its topics and sub-topics. This is the whole examinable outline for Petroleum Production Operations in GATE Petroleum Engineering, not a summary of it.

1. 1

   Well Equipments

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

2. 2

   Well Completion Techniques

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

3. 3

   Well Production Problems and Mitigation

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

4. 4

   Well Servicing & Workover Operations

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

5. 5

   Workover & Completion Fluids

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

6. 6

   Formation Damage

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

7. 7

   Well Stimulation Techniques

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

8. 8

   Artificial Lift Techniques

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

9. 9

   Field Processing of Oil & Gas

   overview

   Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

10. 10

    Storage and Transportation of Petroleum and Petroleum Products

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

11. 11

    Metering and Measurements of Oil & Gas

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

12. 12

    Production System Analysis & Optimization

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

13. 13

    Production Testing

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

14. 14

    Multiphase Flow in Tubing and Flow-lines

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

15. 15

    Nodal System Analysis

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

16. 16

    Pressure Vessels, Storage Tanks, Shell and Tube Heat Exchangers

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

17. 17

    Pumps and Compressors

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

18. 18

    LNG Value Chain

    overview

    Examined as a single unit within Petroleum Production Operations — no further topic split in the official outline.

Petroleum Production Operations flashcards for GATE Petroleum Engineering

25 of 51 cards from the Petroleum Production Operations deck — real questions with worked answers.

1. Define petroleum production operations (the upstream activity).

   It is the set of surface and subsurface activities that bring hydrocarbons from the reservoir to the wellhead and then through gathering, separation, treating, measuring and storage so the oil and gas are made ready for transport and sale.

2. What is the Inflow Performance Relationship (IPR)?

   A plot/relationship between the bottomhole flowing pressure ($p_{wf}$) and the corresponding production rate ($q$) for a well, describing the reservoir's ability to deliver fluid into the wellbore.

3. State the steady-state radial inflow (Darcy) equation for an oil well.

   $$q_{o}=\frac{2\pi k h (p_{e}-p_{wf})}{\mu_{o} B_{o}\,\ln(r_{e}/r_{w})}$$ where $k$ is permeability, $h$ pay thickness, $\mu_o$ oil viscosity, $B_o$ formation volume factor, $r_e$ drainage radius and $r_w$ wellbore radius.

4. Define the Productivity Index (PI or $J$) of a well.

   $$J=\frac{q}{p_{r}-p_{wf}}$$ the production rate per unit pressure drawdown, expressed in $\text{STB/day/psi}$ (or $\text{m}^{3}/\text{day/kPa}$).

5. Write Vogel's IPR equation for a saturated (solution-gas-drive) reservoir.

   $$\frac{q_{o}}{q_{o,max}}=1-0.2\left(\frac{p_{wf}}{p_{r}}\right)-0.8\left(\frac{p_{wf}}{p_{r}}\right)^{2}$$

6. What is skin factor ($s$) and what does its sign indicate?

   $s$ is a dimensionless factor representing extra (or reduced) pressure drop near the wellbore from formation damage or stimulation. $s>0$ means damage; $s<0$ means stimulation/improvement; $s=0$ means no damage.

7. How does skin appear in the pseudo-steady-state inflow equation?

   $$q_{o}=\frac{k h (p_{r}-p_{wf})}{141.2\,\mu_{o} B_{o}\left[\ln(r_{e}/r_{w})-0.75+s\right]}$$ (field units); the $+s$ term adds the skin pressure loss.

8. Define flow efficiency (FE) of a well.

   $$FE=\frac{J_{actual}}{J_{ideal}}=\frac{p_{r}-p_{wf}-\Delta p_{skin}}{p_{r}-p_{wf}}$$ the ratio of actual productivity index to the ideal (zero-skin) productivity index.

9. What is Tubing Performance Relationship (TPR) / Vertical Lift Performance (VLP)?

   The relationship between flow rate and the bottomhole flowing pressure required to lift fluids up the tubing to surface, accounting for hydrostatic, friction and acceleration pressure losses.

10. How is a well's natural operating point determined?

    By nodal analysis: the operating rate and pressure occur at the intersection of the IPR (inflow) curve and the TPR/VLP (outflow) curve, where inflow supply equals outflow demand at a chosen node.

11. List the three components of pressure drop in vertical multiphase flow in tubing.

    Hydrostatic (gravity/elevation) loss, frictional loss, and acceleration (kinetic) loss; the gravity term usually dominates in production tubing.

12. What is artificial lift and why is it used?

    Any method that adds energy to the wellbore fluids to raise them to surface when reservoir pressure is insufficient for economic natural flow; it increases drawdown and production rate.

13. Name the major categories of artificial lift methods.

    Sucker-rod (beam) pumping, gas lift, electric submersible pump (ESP), progressing cavity pump (PCP), hydraulic (jet/piston) pumping, and plunger lift.

14. Explain the principle of gas lift.

    High-pressure gas is injected through gas-lift valves into the tubing to aerate the fluid column, reducing its average density and hydrostatic pressure so the reservoir can lift the lighter column to surface.

15. Distinguish continuous-flow from intermittent gas lift.

    Continuous gas lift injects gas steadily to lighten the column for moderate-to-high productivity wells; intermittent gas lift injects gas in slugs at intervals to displace accumulated liquid in low-productivity/low-pressure wells.

16. How does a sucker-rod (beam) pumping unit lift fluid?

    A surface prime mover drives a walking beam that reciprocates a rod string connected to a downhole plunger pump; standing and traveling valves alternately admit and lift fluid on the up- and down-strokes.

17. What is the function of the standing valve and traveling valve in a rod pump?

    The standing valve (in the barrel) opens on the upstroke to let fluid enter the pump and closes on the downstroke; the traveling valve (in the plunger) closes on the upstroke to lift fluid and opens on the downstroke to let fluid pass into the plunger.

18. When is an Electric Submersible Pump (ESP) the preferred lift method?

    For high-volume, high-water-cut wells with relatively low gas-oil ratio and sufficient bottomhole temperature limits; ESPs are multistage centrifugal pumps driven by a downhole electric motor.

19. What is a Progressing Cavity Pump (PCP) best suited for?

    Viscous, heavy oils and fluids with sand or solids; it is a positive-displacement single-helix rotor turning in a double-helix elastomer stator, producing low shear and steady flow.

20. Define the gas/oil ratio (GOR) in production operations.

    $$GOR=\frac{\text{volume of produced gas (scf)}}{\text{volume of produced oil (STB)}}$$ the ratio of gas to oil produced at standard conditions.

21. Define water cut (WC).

    $$WC=\frac{q_{w}}{q_{w}+q_{o}}\times 100\%$$ the fraction (or percentage) of water in the total produced liquid stream.

22. What is the purpose of a separator in surface facilities?

    To physically separate the produced wellstream into its gas, oil and water phases using gravity and momentum so each phase can be measured, treated and transported separately.

23. List the four mechanisms/sections of a typical oilfield separator.

    Primary separation (momentum/inlet diverter), gravity settling section, coalescing/mist-extraction section, and liquid collection (with level control); they remove gas from liquid and liquid mist from gas.

24. Compare two-phase and three-phase separators.

    A two-phase separator splits the stream into gas and total liquid; a three-phase separator additionally separates the liquid into oil and water, providing separate oil, water and gas outlets.

25. Compare vertical and horizontal separators.

    Vertical separators handle high GOR/low liquid and surging flow, occupy small footprint, and handle sand well; horizontal separators give more gas-liquid interface area, are best for high-liquid/foaming and three-phase service, but need more plot space.

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