Final Exam Review Flashcards

1
Q

A well is drilled in a consolidated sandstone reservoir. The wellbore is believed to be stable and there is no concern about excessive water production. The most economical completion type is _____.

A

open hole

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2
Q

A well is drilled in a limestone reservoir. Resistivity logs reveal there are intervals of high water saturation throughout the producing interval that need to be avoided. The best completion type for this well is _____.

A

cemented and perforated casing

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3
Q

If Swc = Swirr in a reservoir penetrated by a particular well, and in the absence of any hydraulic connection to an aquifer, the producing water cut will be _____.

A

zero

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4
Q

A producing oil well makes 80 BOPD and 20 BWPD. The producing water cut and corresponding WOR, respectively, are _____.

A

20%, 0.25 BW/BO

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5
Q

A production well producing from a reservoir under waterflood has a 99% water cut and a GOR of 50scf/STB. The best representation of reservoir inflow performance will be _____.

A

straight line

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6
Q

A production well produces from a reservoir with an average reservoir pressure of 5000psi. The bottomhole flowing pressure is 3000psi. The oil bubble point pressure is 4250psi. The best representation of reservoir inflow performance will be _____.

A

generalized vogel

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7
Q

The Vogel method is employed to predict the reservoir inflow rate for a well that has a significant, positive skin factor. The inflow rate predicted by the Vogel method in this case would be _____.

A

erroneously high

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8
Q

During normal primary production operations, how will a well’s future productivity index typically compare to its present productivity index?

A

less than or the same

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9
Q

What is most important when assessing the potential performance of a horizontal well over a vertical well?

A

vertical permeability and geometry of the drainage area

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10
Q

Which type of flow will tend to result in the LEAST change in pressure over the length of the flow path

A

slug flow

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11
Q

T or F: if the tubing head pressure in a production well experiencing two-phase flow is decreased by 10%, the bottomhole flowing pressure will also always decrease by exactly 10%.

A

False

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12
Q

If the size of the wellhead choke is increased, the THP is expected to _____ and the surface flow rate is expected to _____.

A

decrease, increase

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13
Q

Artificial lift techniques are designed to overcome the pressure loss in the production tubing string. This may be accomplished by

A

lightening the produced fluid column and adding pressure to supplement pwf

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14
Q

What artificial lift method is preferred for producing a high volume, high water cut, low GLR oil production well?

A

electric submersible pump

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15
Q

What artificial lift method is preferred for producing a high volume, high water cut, low GLR oil production well?

A

electric submersible pump

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16
Q

What artificial lift method is commonly employed to periodically remove a small volume of liquid from a gas well?

A

plunger lift

17
Q

In a continuous gas lift oil production well, the average produced fluid pressure gradient about the operating valve is influenced by

A

the combination of supplemental gas injection and natural formation gas

18
Q

What type of plunger is recommended for use in a well with deviations in the internal diameter f the tubing string?

A

pad-plunger

19
Q

What type of plunger is ideal for removing sand from the inside walls of the tubing string?

A

brush-plunger

20
Q

The Foss and Gaul Method for plunger lift design accounts for _____, _____, and _____.

A

required pressures, gas required per plunger cycle, maximum number of plunger trips possible per day

21
Q

An electrical submersible pump is design to maintain: a) a constant production rate, b) a constant amount of output measured in feet of head

A

b) a constant amount of output measured in feet of head

22
Q

In the operation of an electrical submersible pump, the _____ adds kinetic energy to fluid by accelerating it while the _____ converts part of the added kinetic energy to fluid pressure by slowing accelerated fluid.

A

impeller, diffuser

23
Q

The vertical lift component of the total dynamic head calculated to size an electrical submersible pump is measured from the _____.

A

working fluid level

24
Q

What artificial lift method is preferred for producing wells with low productivity indexes?

A

sucker rod pumping

25
Q

List three changes that can be made to alter the pumping capacity of a sucker rod pumping system.

A

Stroke length, pump rate, and plunger diameter

26
Q

In a sucker rod pumping system, what is the main factor limiting the pumping depth that can be achieved?

A

tensile strength of the rods

27
Q

What is the valve action during the upstroke of a pumping cycle?

A

The traveling valve (TV) is closed and the standing valve (SV) is open

28
Q

What device is employed in a sucker rod pumping system to minimize tubing stretch?

A

a tubing anchor

29
Q

The most cost effective way to achieve downhole gas separation in a sucker rod pumping system is to simply place the pump where?

A

below the perfs

30
Q

What is the tapered string API designation for a sucker rod pumping string composed of 3/4in - 5/8in - 1/2in rods?

A

64

31
Q

What failure mode accounts for 99% of all sucker rod string failures?

A

fatigue

32
Q

What is the maximum polished rod load a C160D-173-64 pumping unit can tolerate?

A

17.300lbs

33
Q

At typical pumping speeds, use of the surface stroke length in design calculations will typically lead to overestimating or underestimating the pump displacement?

A

overestimating

34
Q

At typical pumping speeds, use of the surface stroke length in design calculations will typically lead to overestimating or underestimating the pump displacement?

A

overestimating

35
Q

The polished rod horsepower (PRHP) of a sucker rod pumping system is equivalent to what feature of a surface dynamometer card?

A

the area

36
Q

_____ results from incomplete sucker rod pump working barrel fillage during the upstroke portion of the pumping cycle.

A

Liquid pound

37
Q

_____ results from gas completely filling the sucker rod pump working barrel resulting in no surface liquid production.

A

Gas lock