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Reduce Cost for Petroleum Exploration with Training on your project Service (15$ per hour)

Reduce Cost for Petroleum Exploration with Training on your project Service (15$ per hour)

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Learn and achieve your target with all support you need to build your exploration project  and use modern workflow with less money, you can get more with small budget, we offer professional team in different petroleum exploration fields .

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·         Only 10 $ per hour , different professional consultant more than 10 years

Self-training team

Mr. TAHA MOHAMED TAHA ALI: professional specialist, more than 35 year experience in oil and gas multinational companies, expert in geophysical, geological interpretation and oil business management.

Mr. Adel H akem: professional specialist, more than 35 year experiences in seismic and VSP acquisitions in multinational companies in different countries.

Dr. Bassem Naby: professional specialist, more than 25 in core analysis and reservoir charracterization

Sameh Mohammad Sakr: professional specialist more than 15 year experiences in rock physics, seismic inversion in different inversion software.

Mohamed Ramadan: professional specialist, more than 10 year experiences in geological interpretation in different basins.

Mohamed Samir: professional specialist more than 8 years expert in petrophysic and well log analysis in different Petrophysics software.

Mohamed Ibrahim Shihataa: : professional especialist more than 8 year experiences in different geosciences softwares, expert in seismic attributes and unconventional seismic interpretations in different software application.

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seismic attributes types and callisifications

advantages of borehole seismic (VSP)

 advantages of borehole seismic (VSP)

Borehole Seismic definition

• The name given to seismic surveys, where the seismic sensors are normally lowered into the well bore. The seismic sensors may be single component, 3 component, and could be deployed at single levels, or several levels in the well bore

Why borehole seismic?

• ·         The  comparison    between   a seismic   section  (in two-way  time)  and an acoustic  log (interval  transit time  versus  depth ) leads  to questions  about  the relations     between   the  two  types  of  data  and  the possible     combination    of  their   corresponding datasets 
• ·         The   acoustic   log provides   an obvious   link between geophysics,   seismic   and well   logging data.   Although  covering  different  frequency  bands (acoustic   logs:  in the  order  of  10 kHz;   seismic: ranging   from   about    10 to   I 00  Hz),   the   two techniques    are  based  on  the  same  Jaws  of  wave propagation   but with  different  mythologies.   Under a certain     number   of conditions,   the   seismic measurements      collected    at   these    different frequencies   can be compared   and used to improve knowledge    of reservoir characteristics.    Acoustic log has a very different vertical and lateral range of investigation    compared   with   seismic    surveys (surface or borehole)

the depth-to-time conversion  of well log data is  carried out using the acoustic velocities of formations  obtained from acoustic  logs (sonic logs),  this  method  is  insufficient  to provide  an effective comparison between seismic and logging survey  datasets.   There are discrepancies between the acoustic velocities derived from logging and seismic surveys, it is thus necessary to perform a sonic calibration for the depth-time conversion .

• ·         The sonic log calibration involves establishing a time-depth relation consistent   with the seismic survey yielding the same vertical resolution provided by the sonic log. In other words, the sonic log measurements are recalculated to be compatible with variations in fluid and lithological composition, so the integrated travel time between two depth readings can be matched with the corresponding data from well velocity surveys.
•  A well velocity (or check shot) survey is carried out by measuring the travel times of head waves emitted from a surface shot by means of a geophone or an hydrophone placed at various depths in a well. Check shot surveys   are the predecessor of vertical seismic profiles. Vertical seismic profiles (VSP) may use more sophisticated tools to record the entire seismic wave train generated by surface source and transmitted through the earth filter downward. A VSP survey is usually recorded at a much higher density of depth points but may not cover the entire wellbore.
• Once the calibration has been carried out and a corrected time-depth relation established,  it is possible to compare the well (logs) with surface seismic   data.  One technique employed for this purpose is the creation of a synthetic seismogram using density and acoustic velocity logs. Bulk density and acoustic velocity logs are used to create an acoustic impedance log.  After depth-time conversion, the reflection coefficients derived from the acoustic impedance log are then convolved with an appropriate wavelet to produce the synthetic seismic section (often referred to as a seismogram).                  
•    Seismic data obtained from the vertical seismic profile (VSP) with or without source offset, are processed   to provide seismograms   at seismic frequencies that are directly comparable with synthetic sections   and surface seismic   sections. Even  though  these  data  have  a poorer  vertical resolution compared with  well  logging  and  a restricted  frequency  range,  they can be used  to adjust  profiles  obtained  from  seismic  reflection surveys  carried  out at the surface.   In addition, borehole seismic surveys can be used for defining appropriate operators for stratigraphic deconvolution and converting seismic sections to acoustic impedance sections or logs.

More questions that BHS could answer:

☯ Where is my reservoir top on my seismic section?

☯ Are there faults near my borehole?

☯ How far my reservoir laterally extends?

☯ Where is my desired formation top in the well below TD?

☯ Is there overpressure zone below TD?

☯ I want to make synthetic seismograms!

☯ I want to make a velocity model at the well location!

☯ I need information to better process my surface seismic

data!

Objectives of Well-Seismic Ties

• ·         The objectives for performing a well-seismic tie are listed here
• ·         Wells, of course, are registered in units of depth – feet or meters
• ·         Seismic data is recorded and usually worked with a vertical scale of 2-way travel time
• ·         To relate well data to seismic data, and vice versa, we have to handle this change in vertical scale units 
•       Well-seismic ties allow well data, measured in units of depth, to be compared to seismic data, measured in units of time
•      This allows us to relate horizon tops identified in a well with specific reflections on the seismic section
•   We use sonic and density well logs  to generate a synthetic seismic trace  The synthetic trace is compared to the real seismic data collected near the well location
•   The well-seismic tie is the bridge we need to go from seismic “wiggles” to the rocks that produced the “wiggles” and our interpretation of the subsurface geology (figure 22)
•    The purpose and required accuracy of a well-seismic tie varies with the stage of our studies
• If we are doing regional mapping, e.g., mapping a significant erosional unconformity or a flooding surface, then our tie does not need to be very precise, within 1 or 2 seismic cycles (peaks or troughs) – and the seismic data quality does not have to be very good In the exploration stage, we would like to tie well data, e.g., the top of a stratigraphic horizon/marker within ½ a cycl  This requires good seismic data quality
• In the exploitation stage (development & production), we need to not only know the seismic event within ½ a cycle, but the shape of the real and modeled seismic trace should be quite similar

•     For this, we need very good seismic data quality
•     If we obtain a good character (shape) tie between the real and synthetic traces, then:
•   We would then be able to extract various seismic attributes (measures of the seismic wavelets) to predict rock and fluid properties  We may also be able to use a process called inversion to transform the seismic data into an estimate of the rock properties in cross-section views or as a 3D volume (if we have 3D seismic data)

What is principles microseismic for oil and gas production?

What is principles microseismic for oil and gas productio?

Introduction for microseismic

Microseismicity can be generated by a variety of human activities, including cer- tainindustrial activities that alter either the state of stress or pore  pressure in rocks (McGarr et al., 2002). These geomechanical changes can result in the creation of new fractures or deformation of preexisting fractures

• microseismic used for almost  unconventional reservoir  around the world
• there are two types for microseismic surface and dwonhole, surface microseismic  was started to use in 2003 for fracture detection .
• microseismic is small earthquake result 
• Identify a potential hydrocarbon-bearing reservoir.
• Evaluate the reservoir by hydraulically fracturing vertical pilot wells.
  
• Appraise the viability of horizontal drilling with multiple hydraulic fractures along the length of the borehole.
  
• Optimize commercial development with multiple horizontal wells drilled from a single drilling pad. Full-scale field development.
  
  
  

  

  
  
  
  
  a very low intensity series of earthquakes in very small area where there are no mainshoke. In addition to having natural tectontic causes, they may also be seen as a result of underground nuclear testing occur often near volcanoes as they approach an eruption, and frequently in certain regions exploited for,. These occur so continuously that usually shows a substantial number of small earthquakes at that location.

  • Microseismic man made

    Man-made microseismicity is usually induced by high-pressure injection in ahydrocarbon reservoir for deliberately fracturing rock and increasing the permeability and porosity of underground formations surrounding a producing well and the flow of oil and/or gas to the well.
      
    Microseismic monitoring has also been used in the surveillance of accidents related to heavy-oil production, such as well-casing failures, cement cracking, and unintended fluid flow
    
    

     Development of microseismic

    •it has helped hydraulic fracture stimulation to transform huge volumes of previously uneconomic rock into productive hydrocarbon reservoirs (Stewart, 2009). Stimulated production from methane-rich coal beds, gasbearing shales, and tight sandstone formations has contributed hugely to the continued growth of the oil and gas industry worldwide.

     

    

     

    How It Works

    
    
    Microseism theory is rooted in earthquake seismology. Like earthquakes, microseisms emit elastic waves—compressional (“p-waves”) and shear (“s- waves”), but they occur at much higher frequencies and generally fall within the acoustic frequency range of 200 Hz to more than 2000 Hz. A hydraulic fracture induces an increase in the formation stress proportional to the net fracturing pressure as well as an increase in pore pressure due to fracturing fluid leakoff.
    
    

    Hydraulic stimulation of reservoirs

     
    Hydraulic stimulation is a technique to induce fractures in hydrocarbon and geothermal reservoirs.
     
    •It is injection of fluids under high pressure in order to overcome minimum stress and open a hydraulic fractures, either by opening existing fractures or producing new ones.
    •It increases the permeability of the rock from microdarcy to millidarcy range.
    •The fluid injected into the formation is typically composed of  brine (95%), additives, proppant (e.g. resin-coated sand, ceramic materials).
    •The stimulated volume can extend several hundred meters around the well. The dimensions, extent, and geometry of the induced fractures are controlled by pump rate, pressure, and viscosity of the fracturing fluid.
    •Reservoir hydraulic stimulations usually induce (significant) microseismic activity.