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VSP ZERO OFFSET

Unconventional Seismic Interpretations Using Seismic Attributes workshop using opendTect software

Unconventional Seismic Interpretations Using Seismic Attributes workshop using opendTect software

This five day Unconventional Seismic Interpretation Course is designed for E&P professionals and aims to provide 

essential knowledge on visualization, integration, and interpretation techniques that have been recently developed for seismic data. This course assumes an advanced knowledge of seismic interpretation and concentrates on the role of the seismic attributes in the search for oil and gas.

Course Objectives:

By the end of this course delegates will learn about:

·         To acquire skills in interpretation of 3-D seismic data using seismic attributes

·         Effective using new seismic interpretation techniques (geobodies extraction, multiattributes, hybrid attributes)

·         To enhance theoretical knowledge of seismic structural interpretation, stratigraphic interpretation, reservoir identification and evaluation, and horizon and formation attributes

·         Be familiar with seismic interpretations software

Content

Day 1

·         INTRODUCTION       

·         SEISMIC INTERPRETATION WORKFLOW 

·         Conventional Techniques of Seismic Interpretation    

·         Unconventional Techniques of Seismic Interpretation Using Seismic Attributes

·         Definition of seismic attributes           

·         Classification of seismic attributes      

·         Calibration seismic attributes methods

Day 2

·         DATA PRECONDITIONING 

·         Filters without Edge Preserve  

·         Filtering with Edge Preserved  

·         Workflow to Enhance Seismic Attributes Result Attribute.     

·         GEOMETRIC ATTRIBUTES  

DAY 3

·         PHYSICAL ATTRIBUTES

·         INSTANTANEOUS ATTRIBUTES    

·         Envelope        

·         Dominant Frequency  

·         Average Energy Attributes      

·         Instantaneous Frequency        

·         Sweetness                   

·         SPECTRAL DECOMPOSITION ATTRIBUTES         

·         CURVATURE ATTRIBUTE  

·         MULTI -ATRIBUTES DISPLAY        

DAY 4

·         HYPRIDE ATTRIBUTES

·         CASE STUDY I: THIN BED GEOLOGICAL FEATURES IDENTIFICATION USING SEISMIC ATTRIBUTES

·         PREVIOUS STUDY FOR SHALLOW CHANNEL DETECTION          

·         QC SEISMIC DATA      

·         SMOOTH MEAN FILTERS FOR ENHANCING SEISMIC DATA        

·         AVERAGE SD ATTRIBUTES APPLICATION IN THIN CHANNELS 

·         REAL Average SD AMPLITUDE Attributes Workflow 

·         DISCUSSION

DAY 5

CASE STUDY II: Gulf Of Mexico FIELD         

·         DATA PRECONDITIONING 

·         GENERATING SEISMIC ATTRIBUTES FOR IDENTIFYING STRATIGRAPHIC FEATURES        

·         EXTRACTING GEOBODIES FROM SEISMIC ATTRIBUTES          

·         Extracting Shallow Channel    

·         Extracting Deep Channel.       

·         CROSSPLOT ATTRIBUTES  

·         DISCUSSION 

CASE STUDY III: NORTH SEA FIELD   

·         MULTI-ATTRIBUTES FOR ENHANCING GAS CHIMNEY IMAGE

·         FAULT IMAGE ENHANCEMENT    

·         Ant tracking algorithm Illuminator attributes   

·         SEISMIC ATTRIBUTES INTERPRETATION

·         AVERAGE SD ATTRIBUTES APPLICATION FOR CHANNEL DETTECTION       

·         DISCUSSION

 My contact 

Skype: self tranning 

Facebook: https://www.facebook.com/Initiative.Courses

Mail: selftrainning@gmail.com

Phone: +201120828201 -01201141235

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self trainning Petroleum: Reduce Cost for Petroleum Exploration with Trainin...

self trainning Petroleum: Reduce Cost for Petroleum Exploration with Trainin...: Reduce Cost for Petroleum Exploration with Training on your project Service (15$ per hour) training on project Learn and achie...

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)

training on project

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 .

·         online services for all geological and geophysical applications ,

·         24 hour per day,

·         Arabic and English language ,

·         Practical and theoretical support for exploration and production oil and gas,

·         Recorded videos.

·         Professional Technical consultant team .

·         Assistance for build G&G projects and creation good plan and reduce cost for oil exploration.

·         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.

http://www.youtube.com/watch?v=JfdyQL2Q4Go

http://www.linkedin.com/groups/Self-training-courses-5187709?trk=my_groups-b-grp-v

https://www.facebook.com/Initiative.Courses

http://geocourses.webs.com/

My contact 

Skype: self tranning 

Facebook: https://www.facebook.com/mohamed.i.shihata

Mail: mohammed_ mohammed4533@yahoo.com 

Phone: +201120828201

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)