Production Adrian

Front 1

It is a process used to establish a flow path between the near reservoir and the wellbore

Back 1

Perforating

Front 2

It normally involves initiating a hole from the wellbore through the casing and any cement sheath into the producing zone.

Back 2

Perforating

Front 3

These are an elemental piece of the inflow section of the well and have significant impact on the total completion efficiency

Back 3

Perforations

Front 4

Are characterized by extreme energy release in a very short time, some with detonation front movement on the order of 6100+ m/s (20,000+ ft/sec).

Back 4

High explosives

Front 5

Mention some examples of high explosives to establish a flow path between the wellbore and the sandface

Back 5

RDX, HMX, PYX, HNS

Front 6

These explosive materials are designed to generate energy at a slower rate than the high explosives, and their primary function is to provide quick fluid volume.

Back 6

Gas generators

Front 7

These materials are used for power fluids (gas drive), fracturing energy, and propulsion energy sources.

Back 7

Gas generators

Front 8

It is a term associated with explosive firing

Back 8

Order

Front 9

This terms refers to the high explosive has been initiated properly and reacts at the maximum speed.

Back 9

High order

Front 10

It refers to a high explosive fails to achieve maximum energy; the explosive may react, but the energy level produced is sharply lower than the maximum potential.

Back 10

Low-order

Front 11

It is an explosive that is used in initiators or other devices to initiate the explosive sequence

Back 11

A primary explosive

Front 12

How are called the detonators?

Back 12

blasting caps

Front 13

It is a measurement of how close flow capacity in the perforated hole approaches the flow capacity of an ideal hole of the same diameter and length

Back 13

Perforation flow efficiency

Front 14

This is pressure differential from the wellbore toward the formation

Back 14

overbalance

Front 15

This is pressure differential from the formation to the wellbore

Back 15

Underbalance

Front 16

This term refers to the angle between the charges

Back 16

Phasing

Front 17

Which are the most common phasings?

Back 17

0°, 180°, 120°, 90°, and 60°.

Front 18

It is the measurement of the perforations made per unit length of the gun

Back 18

Shot density

Front 19

Which are the ranges of shot density?

Back 19

From 1 to 27 SPF.

Front 20

It is a measurement of the hindrances in the flow system

Back 20

Pressure drop

Front 21

Which are the main factors to consider for establish an optimal flow path?

Back 21

The differential pressure, the permeability of the system, the fluid viscosity, and the length and area of the flow path.

Front 22

Which were the first commercial perforating devices?

Back 22

Bullet guns

Front 23

When was commercialized the bullet guns for perforating?

Back 23

The early 1930s

Front 24

This technology was accepted by the oil industry in the late 1940s and early 1950s and became the most used perforating method by the mid- to late 1950s.

Back 24

The bazooka, with its armor-piercing charges

Front 25

This method is a function of the density and strength of the target in its path, as well as gun performance factors

Back 25

Bullet penetration

Front 26

This artefact seals quickly and efficiently on bullet perforations.

Back 26

Perforation ball sealers

Front 27

The advantages of these perforations are the high permeability connection to the immediate reservoir and very controlled hole size and shape

Back 27

bullet perforating

Front 28

The disadvantages of these perforations are shallow penetration, ineffectiveness in hard formations and high alloy or heavy pipe, leaving a solid mass of steel in the perforation tunnel, and low density perforating

Back 28

bullet perforating

Front 29

These methods use high-volume flow of abrasive-laden fluid to erode through the target pipe or cut it off when the nozzle or tubing string is rotated

Back 29

Abrasive perforating methods

Front 30

Which are the most common abrasive material for perforating and pipe cutoff?

Back 30

Sand

Front 31

What is the single most erosive material in the abrasive process?

Back 31

Bauxite

Front 32

These tools are used to create perforation tunnels in openhole completions.

Back 32

Water Jets

Front 33

The shaped charge are also called :

Back 33

“jet” perforator

Front 34

This tool uses a small amount of high explosive and a carefully shaped case and liner to create a focused pressure punch that is highly effective in piercing steel, cement, and rock.

Back 34

The shaped charge or “jet” perforator

Front 35

These are tapering tubes of usually less than 0.8 in. (2 cm) diameter at the entrance hole in the casing and depth of 1 in. (2.5 cm) to more than 30 in. (74 cm).

Back 35

Perforations

Front 36

What is the most common flow behavior in longer perforations?

Back 36

Radial flow with some pseudoradial

Front 37

What do include the charge variables?

Back 37

Propellant type, size, and design.

Front 38

Which are the main parts of shaped-charge perforator?

Back 38

Primer, case, liner and powder

Front 39

Mention the main purpose of shaped-charge perforator design

Back 39

To maximize either entrance hole or tunnel penetration.

Front 40

When the jet penetrates the formation from shaped charge to the formation; What is the effect in the formation?

Back 40

Creates a zone of lowered permeability.

Front 41

It is a reflection of how much and what type of fluids that the formation can deliver to the wellbore

Back 41

Flow capacity

Front 42

This phasing normally is used only in the smaller OD guns or guns in very large casing.

Back 42

0°

Front 43

What is the most important characteristic in a perforation design?

Back 43

Perforation length

Front 44

This charge spends the bulk of its energy creating a long tunnel

Back 44

The deep-penetrating charge

Front 45

This charge focuses its energy on the casing wall and creating hole diameter

Back 45

The big-hole charge

Front 46

How can be determined the shot density for a well?

Back 46

Nodal analysis simulator

Front 47

How is called the new zone created by the explosion of the charges?

Back 47

crushed zone

Front 48

Which are the mechanisms to improve flow capacity in the perforations?

Back 48

"Underbalanced perforating, extreme overbalanced perforating, surging, or one of several breakdown actions"

Front 49

This mechanism drives the wellbore fluid into the perforation and has the capacity to create particulate damage in the perforations

Back 49

overbalanced perforating

Front 50

What is one of the best methods for creating open, undamaged perforations in which the permeability is high enough to create sufficient flow rate to break the crush zone loose and carry it out of the perforation tunnel?

Back 50

Underbalance perforating

Front 51

It is a microfracture-initiating process that is applied at the moment of initial perforating or as a surge process to existing perforations

Back 51

Extreme Overbalance Perforating (EOP)

Front 52

This process deliver a pressure pulse that achieves the same type of breakdown as the fluid, but with minimum equipment

Back 52

explosive propellant

Front 53

Which are the factors to consider for collapse resistance of the casing?

Back 53

Depends on the number of holes in the pipe, the hole size, and their alignment (shot phasing).

Front 54

What kind of casing reduces the penetration of any perforating charge?

Back 54

Concentric casing strings

Front 55

What do determine the number of perforations needed for well production?

Back 55

The inflow potential

Front 56

Which are the two basic carriers in shaped-charge perforators?

Back 56

The retrievable hollow carrier and the expendable or semiexpendable carrier

Front 57

These guns can be run either on wireline or on tubing. They may carry large charges, which normally minimize casing damage.

Back 57

Hollow-carrier guns

Front 58

This tool contains the exit burr from the charge firing, which prevents scoring of polished bores if the gun is moved after firing and may minimize gun swelling.

Back 58

The scallop

Front 59

These guns have charges that are exposed to well fluids and pressures and are popular for through-tubing applications.

Back 59

Expendable guns

Front 60

Mention two factors that affect the charge performance in hollow-carrier perforators

Back 60

Standoff and gun clearance

Front 61

It is the distance between the base of the charge and the inside of the port plug or scallop and is a fixed part of the gun/charge system design.

Back 61

Standoff

Front 62

It is the distance from the outside of the port plug or scallop to the wall of the casing.

Back 62

Gun clearance

Front 63

The charges are fired by this artefact

Back 63

An initiator or detonator

Front 64

How are also called the standard explosives detonator?

Back 64

blasting cap

Front 65

These systems may be electric line, tubing, coiled tubing, pumpdown, or even slickline.

Back 65

Conveyance Systems.

Front 66

Through this device the hollow-carrier guns can be run through the production tubing and packer and require only a service truck-based unit

Back 66

The tubing-conveyed perforating

Front 67

In these methods, the perforating gun is attached to the outside of the casing string, and the guns are deployed during the initial running of the casing string.

Back 67

The casing-conveyed perforating

Front 68

What are the methods to depth control for perforating?

Back 68

The gamma ray tie-in and correlation to the original openhole gamma ray system.

Front 69

This charge is designed to expend all its energy penetrating the wall without forming additional penetration.

Back 69

The tubing puncher charge

Front 70

These methods are useful during salvage operations, fishing operations, certain production operations, and any action that requires severing the tubing

Back 70

Tubing cutoff

Front 71

Which are the most common pipe cutoff methods?

Back 71

explosive or chemical cutters

Front 72

This kind of cutting fluid method reacts extremely quickly and generates intense heat

Back 72

Chemical cutters

Front 73

These explosives produce a pressure wave that is oriented outward and usually produce a flare in the steel at the cut point

Back 73

Radial explosive cutters

Front 74

This method can be used successfully on both jointed and coiled tubing applications to sever pipe.

Back 74

Mechanical cutters

Front 75

These cutters use a particulate such as sand, glass beads, or calcium carbonate pumped through a rotating nozzle, and the abrasion erodes the steel.

Back 75

Abrasive cutters

Front 76

It refers to any unintended impedance to the flow of fluids into or out of a wellbore

Back 76

Formation Damage

Front 77

It is a dimensionless pressure drop caused by a flow restriction in the near-wellbore region.

Back 77

Skin factor

Front 78

Who and when was introduced the concept of well flow efficiency?

Back 78

In 1970, Standing

Front 79

How is the flow efficiency in a stimulated well?

Back 79

More than 1

Front 80

How is the flow efficiency in a damaged well?

Back 80

Less than 1

Front 81

Which are the mos common methods to evaluate the flow efficiency for oil and gas wells?

Back 81

Multirate tests, isochronal gas-well tests, and transient well tests (pressure-buildup analysis).

Front 82

In these tests, several stabilized flow rates, are achieved at corresponding stabilized flowing bottomhole pressure. These test can be conducted on both oil and gas wells.

Back 82

Multirate Tests

Front 83

What is the most common method for determining skin?

Back 83

Pressure-Buildup Analysis

Front 84

In this test, a well that has been producing for a time then is shut in for time.The pressure buildup is recorded as a function of time.

Back 84

Pressure-Buildup Analysis

Front 85

Throughout this plot it is possible obtain the skin factor as function of the reservoir pressure and the time

Back 85

Horner plot

Front 86

Formation damage mechanisms can be broken down into two broad classes; mention them

Back 86

Near-wellbore permeability reduction and near-wellbore relative permeability changes

Front 87

These effects are a consequence of how the wellbore penetrates the reservoir and where the perforations are placed and permeability loss as a result of depletion

Back 87

pseudoskin effects

Front 88

These fluids used to drill through the pay zone and minimize formation damage

Back 88

drill-in fluids

Front 89

What can be formed by the use of improper mixing producers in dissolving polymers into brines?

Back 89

fish eyes

Front 90

These fluids consist of water droplets dispersed in a continuous oil phase.

Back 90

OBFs

Front 91

In this process solids in the mud are pushed against the formation by a hydrodynamic force that is proportional to the leakoff velocity. Due to this phenomenon it will possible to form a mud cake

Back 91

overbalance pressure

Front 92

It allows fluids from the fracture to flow into the wellbore, keeping the fractures relatively undamaged.

Back 92

Underbalanced drilling

Front 93

Where does exist more damage, in the upper part of the well or bottom of the wellbore?

Back 93

In the bottomhole

Front 94

These fluids do not contain drill solids

Back 94

completion and workover fluids

Front 95

The differential pressure between the cement and the formation fluid can lead to a significant loss of cement filtrate into the formation; How is called this damage?

Back 95

Damage During cementing

Front 96

What does cause a rapid change in cement pH?

Back 96

The formation of inorganic precipitates such calcium carbonate and calcium sulfate.

Front 97

Who investigated the influence of cement filtrates on formation permeability and concluded that there was little evidence of fines migration or clay swelling induced by the cement filtrate?

Back 97

Cunningham and Smith

Front 98

What kind of additives reduced the quantity of precipitate from cement and resulted in less damage to the rock?

Back 98

lignin derivatives or polymer

Front 99

What kind of fines causing the permeability reduction in the sandface?

Back 99

Include clays, feldspars, micas, and plagioclase

Front 100

Which are the most common swelling clays found in reservoir rock?

Back 100

Smectites and mixed-layer illites.

Front 101

This damage reduces formation permeability by peeling off the pore surfaces and plugging pore throats, not by reducing porosity alone

Back 101

Swelling clays

Front 102

Swelling is known to occur in three steps. Mnetion them

Back 102

Crystalline swelling, hydration swelling and free swelling

Front 103

In this swelling step layers of water enter the interlayer space in the clay mineral,resulting in an increase in the C spacing of the clay mineral

Back 103

Crystalline swelling

Front 104

In this swelling step occurs through the hydration and dehydration of ions entering the interlayer region

Back 104

hydration swelling

Front 105

In this swelling step clay layers are sufficiently far apart that very little mechanical integrity exists in the clay

Back 105

Free swelling

Front 106

Why is injected the water into formation?

Back 106

Pressure maintenance, water disposal, or waterflooding.

Front 107

Which are the two main properties of injection water that determine the formation damage?

Back 107

The total dissolved solids in the injection water and the total suspended solids (solids and oil droplets) in the injection water

Front 108

Which are the two types of formation damage in an injection well?

Back 108

Freshwater sensitivity of the formation and precipitation of inorganic scale

Front 109

What is the most common formation damage problem reported in the mature oil-producing regions of the world?

Back 109

Organic deposits forming both in and around the wellbore

Front 110

Which are the two categories of organic deposits in the wellbore?

Back 110

paraffins and asphaltenes

Front 111

These organic deposits can act as chokes within the wellbore, resulting in a gradual decrease in production with time as the deposits increase in thickness.

Back 111

Paraffins

Front 112

What is the primary cause of wax or paraffin deposition?

Back 112

A loss in solubility in the crude oil

Front 113

It is defined as the temperature at which paraffins begin to come out of solution and a clear solution of hydrocarbons turns cloudy.

Back 113

The cloud point

Front 114

It is defined as the temperature at which the crude oil no longer flows from its container

Back 114

The pour point

Front 115

Which are the three metothds to remove Paraffin accumulations?

Back 115

(1) mechanical removal of paraffin deposits, (2) the use of solvents to remove paraffin deposits, and (3) the use of heat to melt and remove the wax

Front 116

What is the most common solvent used to remove paraffin from tubulars and the near-wellbore region?

Back 116

Crude oil

Front 117

These inhibitors are a class of compounds that consist of crystal modifiers that prevent the deposition of paraffin onto pipe surfaces

Back 117

Paraffin inhibitors

Front 118

This part of the crude oil contains nitrogen, sulfur, and oxygen (N, S, and O) compounds

Back 118

Asphaltenes

Front 119

It is defined as the pentane-insoluble fraction of the crude oil

Back 119

Asphaltenes and resins

Front 120

This is a result of mixing and shearing that occur in chokes and valves in the flow stream after the fluids have entered the well

Back 120

surface emulsions

Front 121

These reservoirs are defined as reservoirs that contain hydrocarbon mixtures that on pressure depletion cross the dewpoint line.

Back 121

Gasgas/condensate reservoirs

Front 122

What is the most common method used to remedy condensate buildup problems?

Back 122

Hydraulic fracture stimulation

Front 123

It is defined as the ratio of capillary to viscous forces

Back 123

capillary number

Front 124

Which are the three metothds to remove water blocks in sandface?

Back 124

(1) surging or swabbing the wells to increase the capillary number temporarily; (2) reducing surface tension and (3) the use of solvents or mutual solvents