1. Why run cased hole? . To Assess well integrity. To Improve reservoir management. Scan the well for bypassed production before plugging and abandoning.

2. Lithology Identification GR: measures the strength of natural radioactive material present in the

formation that can distinguish between the sand and shale in siliciclastic

environments.

Natural GR spectroscopy: work in same principle of GR and counts the

contribution of (Ur, Potassium, thorium). Determine relative proportions

of certain minerals in the formation.

3. Determination of reservoir characteristics

4. Differentiate between source rock and non source rock

5. Categories of cased hole logs?1) Formation Evaluation: - Logging tools in this category are designed to evaluate formation

properties. Such as formation shale content, clay type, and vertical

definition of zones which are clean and shale free.

- It also can determine the type of rock (sand, lime, …etc), The type of

hydrocarbon, gas or oil and its saturation

Other information available includes

- Mechanical properties of the rock and mineralogy.

- Permeability of the rock.

- Skin damage.

- Pressure.

- Natural fracture.

- Samples of formation fluids.

2) Well bore integrity

- This category of logs includes the wide variety of logs to evaluate the

cement sheath around the casing. This information provided some

assurance of hydraulic isolation.

- Casing condition in terms of depth and extent of damage may also be

evaluated

3) Fluid movement during production or injection.- This category includes tools which detect channels behind pipe in both

injection and production wells.

- Such tool furthermore defect zones of fluid injected, location of pumped

material such as fracture fluid or proppant.

- It can even directionally detect the orientation of certain injected

particulates.

- Flow profiles in both injection and production may be evaluated along

with the contributions of each phase of produced fluid on a zone by

zone basis, Combined with pressure information, these contributions

may be the basis for determining a zone by zone inflow performance

relationship.

4) Others

- This category is a catch-all for services whose application or

environment may be unusual. For example: the gravel pack logs are

designed to evaluate the presence of gravel outside of a wire wrapped

or slotted liner, a condition which is neither increasing nor out of it

- Another grouping in this category are the stuck point or free point

indicator tools: These are typically not closely related to reservoir

management and are of more immediate operational concern

6. Preparing well logs (exploratory and development)

Typically there will be many items that are conditional on hydrocarbons being

encountered based on shows encountered while drilling for a well proposal , a

typical program might look some thing like this:

Exploration well

“17.5" hole section:

GR/ Resistivity/ Sonic (GR to surface) if shows encountered include GR/

density/ neutron and optional pressure/ fluid samples.

"12.25" hole section:

LWD GR/ resistivity.

Wireline GR/ resistivity/ density/ neutron.

Optial pressure/ fluid samples if hydrocarbon encountered

"8.5" hole section:

LWD GR/ resistivity.

Wireline GR/ resistivity/ density/ neutron.

GR/ Sonic/ Formation imager.

Pressure/ fluid sampling ( sampling dependent on oil being encountered).

VSP.

Side wall samples.

Development Well

"17.5" hole section:

No logs required.

"12.25" hole section:

MWD (measurement while drilling)/GR.

GR/ Resistivity/ Sonic (GR to surface).

if shows encountered include GR/ density/ neutron and optional

pressure/ fluid samples.

"8.5" hole section:

GR/ resistivity/ density/ neutron.

Dipole Sonic/ Formation imager.

Pressure/ fluid sampling ( sampling dependent on oil being encountered).

VSP.

Side wall samples.

7. Difference between log contract and log program?

Mud log unit has two main responsibilities:

To monitor the drilling of the parameters and gas/liquids/solids returns

from the well to assist the drilling department in the safety and

optimization of the drilling process.

To provide information to the petroleum engineering department that

can be used for evaluation purposes

Items that will be included in daily mud log report are:

Gas reading as measured by a gas detector/chromatograph.

A check for absence of poisonous gases (H2S, SO2)

A report of cuttings received over the shale shakers, with full lithological

descriptions and relative percentages.

ROP

Hydrocarbon indication in samples.

But elements that exist in common log contracts include the following:

Depth charge: This relates to the deepest depth that a particular tool

will be run in the hole.

Survey charge: This relates to the interval that a particular tool is

actually logged in the hole.

Station charge: For tools such as formation pressure sampling tools and

sidewall samples, this is a change per station measurements. Usually the

contract will make certain specification regarding when such a charge

may be dropped (e.g., if no useful data are recovered).

Tool rental: Usually a daily charge for the tools to be on the rig on

standby prior to or during a logging job.

Logging unit rental charge: Usually a monthly charge for the logging unit

(winch, tool shed and computers).

Base rental: There may be a monthly charge to have a pool of tools

available for a client. For LWD tools, this may supersede the tools rental,

depth and survey charges.

Engineer charge: Usually a day rate for any engineers, specialists, or

assistants present for the logging job.

In-hole charge: Some LWD contracts specify an hourly charge while tools

are actually being run in the hole.

Lost-in-hole charge: For replacement of any tools lost in the hole during

operations. Some contractors provide insurance to the oil companies for

a fixed sum per job to compensate them against lost-in-hole charge.

Cable splice charge: Where tools become stuck in the hole and it is

necessary to cut the cable, a charge is usually made for such splicing.

Processing charges: Where data require post-processing (e.g.

interpretation of image data or waveform sonic), charges are usually

applied in similar way to survey charges.

Data charge: Provision of additional copies of log prints and/or tapes or

data storage, may incur additional charge.

Real-time data transmission charges: The oil company will usually be

given the option to have data transmitted directly from the well site to

their office

8. Importance of mud logging Identification of the lithology and formation type being drilled

Identification of porous/permeable zones

Picking of coring, casing or final drilling depths.

Confirmation of hydrocarbons bring encountered and whether they are

oil or gas

9. Stratigraphic column (Correct the wrong answer) Gulf of Suez (Zeit, South Ghareb, Balaeem, Kareem, Rudeis, Nukhul,

Esna, Sudr, Matlla, Qada, Abu Qada, Raha, Nubia (A,B,C) )

Western Dessert ( Kurkar, Dabaa, Guindi or Appolonia, Esna,

Khoman,Abu Roash, Bahariya, Medeiwar, Burg el Arab, Elkhataba, Wadi

el Natrun,Masajid, Ras Qttara, Kohla, Zeitoun )

Nile Delta ( Mit Ghamr, El Wastani, Kafr el Sheikh, Qwasem, Sidi Salem)

10.Advantages and disadvantages of different types of artificial lift

Sucker Rod Pump (pump unit): Most common artificial lift method. Used mostly in shallow to

medium-depth oil fields (< 10,000 ft). Surface pumping unit is connected via sucker rods to a down hole

pump. Advantages Electric Submersible Pump (ESP)

Designed to pump at very high flow rates (100 to 10,000 BPD) If conditions are favorable, ESPs can run several years

Disadvantages of ESP Less efficient than other methods Expensive Sensitive to solids and free gas.

Advantages of gas lift:o Can handle large volume of solids with minor problems.o Crooked holes present no problem.o Applicable offshore platforms.o Power source can be remotely located.o Sometimes serviceable with wire line unit.o Easy to obtain down hole pressure and gradient.o Lifting gassy wells is no problem.

o Flexible, easy to change rate. Disadvantages of gas lift:

o Lift gas is not always available.o Not efficient to lifting small fields.o Difficult to lift emulsions and viscous.o Gas freezing and hydrate problems.o Cannot effectively produce deep wells.o Safety problem with high pressure gas.o Required make – up gas in relative system.o Casing must withstand lift pressure.o Problems with dirty surface lines.

11.Compare between types of artificial lift Rod Pumped Wells

Rod pumped wells are probably the most common type of pumping well, especially among wells with low flow rates. These use a horse’s head and walking beam arrangement. The motion of the sucker rods, in turn, operates a pump at the end of the tubing down hole. A special wellhead is required to log such wells and the logging tool is run down the tubing-casing annulus

Electric submersible pumps ”ESP”These are subsurface hydraulic pump located at the bottom of tubing and powered by electrical as hydraulic energy. These generally can’t be logged unless a (Y) tool is situated at the end of the tubing string. This tool allows passage of the logging tool even as pump works

Gas Lift.Gas lift is a method where a gas pumped into the tubing string, thereby removing the heaver fluids present and reducing the hydrostatic pressure on the formation. This type of well can be logged much like a naturally completed well.

12. Reservoir Performance (inflow and outflow)

Reservoir Inflow Performance using bottomhole pressure gauges is routinely measured at regular intervals as part of the field monitoring program. This relationship between flow rate (q) and wellbore pressure (Pwf) is required for a nodal- type analysis of well performance.

Factors affecting the outflow performance (tubing size, flow rate, GLR, WC, Fluid densities and viscosities, Slippage, Temperature Gradient)

13. Production system (IFP, VLP, Beam performance)

1) Inflow performance, which deals with the flow of formation fluid from reservoir into the bottom of the well. The well IPR changes with time (except for steady-state flow). Infinite-acting and pseudo-steady-state conditions where reservoir pressure declines with time: IPR changes with time.

2) Vertical lift performance, dealing with pressure losses through vertical production tubing with producing well. The reservoir deliverability depends on the VLP. The wellhead flowing pressure Pwf is a function of hydrostatic pressure and friction pressure losses. Increase in well head pressure increases pwf accordingly. Two-phase flow is common even if pwf is above Pb. VLP is combined with IPR to estimate the well deliverability.

3) Beam performance, which deal with pressure losses accompanying the flow of fluids which coming from reservoir to the surface choke or bean in flowline at the surface.

14. What is harsh downhole equipment?

Temperature Pressure H2s and CO2

15. Importance of wellhead

Wellhead systems serve as the stop point of casing and tubing strings. As such, these systems control pressure via chockes, valves and others and provide access to the main bore of the casing or tubing or to the annulus. This pressure-controlled access allows drilling and completion activities to take place safely with minimal environmental risk. Multiple barriers are used, such as primary and secondary seals, to reduce risk in case of equipment failure.

16. Factors to consider before artificial lift

- Fluids volumes - Well depth - Expected GLR - Tubular size - Hole deviation - Solids (sand,…) corrosive materials

17. Draw Typical casing tubing configuration of a producing well

18. Draw coil tubing

It is very difficult to run logging when the hole is deviated, this is a result of friction and pore hole conditions

Tool strings having rollers ,sinker bars, special nose guides, and rigidized cable, are used to help

knuckle joints are used to enhance tool flexibility, Where tool strings are long and the tool is not be string to negotiate the curvature of the borehole

Coil tubing equipment is very useful to spot fluid down hole and frequently used for squeeze cementing for logging purposes

The coil tubing, although somewhat flexible, may fail due to buckling or tension during the pushing and pulling of the tool down hole

As a result, computer modeling for the job is advisable prior to the job to assure that the planned job is within the physical capability of the coil tubing