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Module 6 — Condition input data for Seismic well tie To get a good seismic to well tie, it is important to load the checkshot data properly and run quality control on it (or a time/depth relationship) and edit logs. In this module, you learn how to load and quality control checkshot data. You also learn how to prepare logs to use them as input to the seismic well tie workflow.
Learning objectives After completing this module, you will know how to: • load and quality control checkshot data • work with the Seismic Reference Datum (SRD) and Checkshot Reference Datum (CRD) for SWT • define time-depth relationships • use the Log conditioning Tool Palette
Petrel Geophysics
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Condition input data for Seismic well tie •327
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Q. 3
Lesson 1 — Checkshot data loading Loading checkshot data is an important step towards generating a synthetic seismogram. A seismogram provides the time-depth relationship required in Sonic log calibration. It is useful to invest some time in reviewing the checkshot data file before importing it into Petrel.
The checkshot data in Petrel is imported similar to well tops, point well data, and points with attributes. You use the same dialog box with a few modifications.
You can import individual well checkshots simultaneously as well as multiple checkshot data. The dialog box is divided into three sections. At the top of the dialog box is a small template spreadsheet that describes the order and type of data found in the file. Edit the spreadsheet to ensure that data is imported correctly. The central section holds all of the settings required for the import. At the bottom of the dialog box is a text window that displays the first few lines of the file. This window helps you to select the attributes correctly in the top section of the dialog box. To make sure that checkshot data is loaded correctly, it is good practice to take the time to study the attribute selection and understand the purpose of each attribute. Click on an Attribute or Unit entry in the spreadsheet part of the dialog box. A list appears from which you can select attributes. The depth and time datum references can be changed to match the available input datum using these acronyms:
MSL Mean sea level. In the file shown, TVDSS refers to TVD subsurface (MSL) Kelly bushing elevated from MSL KB SRD Seismic reference datum CRD Checkshots reference datum The shaded fields in the Depth and Time sections are entered in the Templates pane during project setup. Refer to the Petrel Help for further details. 328 •Condition input data for Seismic well tie
Petrel Geophysics
>
I Even if time and depth values below MSL are displayed as negative numbers, the spreadsheet numbers (MD, TVD, and TWT) for checkshots are positive. <
Q. 3
If the values are not positive, checkshots must be reloaded. Be sure to select the Negate time values check box in the import dialog box when time and depth values are positive. Load Z-values Make sure that the ASCII file contains negative Z-values. If the Z-values are positive, select the Negate Z values check box. Load TVD or MD values ASCII data must be positive.
Load TWT values Make sure that the ASCII file contains negative TWT-values. If the TWT-values are positive, select the Negate Z values check box.
Possible errors: Quality check As a quality control step for imported checkshot data, it is important to make sure that the time values are negative (Figure 1 ). Negative values are meaningful because all values below mean sea level are treated as negative. If the imported checkshot shows positive values, it means that the data has not been imported properly.
X-Coord 1599743.87 1599743.09 1599743.02 1599738.12 1599732.30 etc
Y-Coord -172747.82 -172748.18 -172748.21 -172747.07 -172747.23
Z TWT MD 95.00 0.00 0.00 -100.00 39.71 195.01 -105.00 41.70 200.01 -304.90 119.30 399.98 -704.80 268.00 799.9
Figure 1 TWT must be negative, in this example we can observe a loading error that must be corrected before moving forward Petrel Geophysics
Condition input data for Seismic well tie •329
>
In Figure 2, the checkshot data (left) is imported incorrectly. The input file contains positive time values and the Negate time values check box is not selected when loading checkshot data. <
Column #
1
2
3
4
Attribute Attribute name
X
Y
Z
TV/T
MD
feet
millisecond
feet
Attribute type Unit
X Y Continuous Continuous File CRS unit File CRS unit
Well name
6
Well TV/T Well Z MD Conbnuou Continuous Conbnuou Text
4 Column # 3 5 6 1 2 Well TV/T Attribute X Y Z MD Attribute name X Y TV/T Well MD Z Continuous Attribute type Continuous Conbnuou Continuous Conbnuou Text Unit File CRS unit File CRS unit millisecond feet feet
Diamond-14
Connect to trace
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Depth Depth datum:
MSL
Negate Z values
Diamond-14
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Depth Depth datum:
Zfrom MSL:
MSL
0 Negate Z values Time
Time Time datum
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SRD
Negate time valuesÿ
330 •Condition input data for Seismic well tie
Time datum:
Zfrom MSL: TWT from SRD
QZ
J.
Negate time valuesÿ
SRD
Undefined value:
9
Zfrom MSL:
Zfrom MSL: TWT from SRD:
Petrel Geophysics
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Procedure — Load checkshot data 1. Right-click the Wells folder and select Import (on selection) to open the Import file dialog box. <
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If multiple files are selected, Petrel prompts you to merge them. Click Yes to merge all data into one checkshot object or No to load each file into separate
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Auto color all Auto name all New well
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Show trajectory providers
Reconnect missing files Well path report Risk manager
Well annotations spreadsheet... Guru
2. Set Files of type to Checkshot format (ASCII) (*.*). Petrel Geophysics
Condition input data for Seismic well tie •331
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3. Select one or more files to import and click Open. fv] Import file book in:
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Check Shots
Name Recent Places
Desktop >1
I'D AIICheckShots.es f | Apatite_E13.cs Pi Copper_6.cs f 1 Diamond_14.cs
_ Dolomite_Bl.cs
t
f
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Date modified
Type
31/07/2005 23:10 30/01/2007 12:27 30/01/2007 12:27 30/01/2007 12:28 30/01/2007 12:28
VSTA.cs.8.0 VSTA.cs.8.0 VSTA.cs.8.0 VSTA.cs.8.0 VSTA.cs.80
Size 89 KB
1KB 2 KB 1 KB 1 KB
2
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Rle name:
AIICheckShots.cs
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Rles of type:
Checkshots format (ASCII) (V)
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□Open as read-only Rle example/description: tt Petrel checkshots format tt Not all attributes are necessary. tt i.e. X. Y. and Z can be left out. as they are derived from md and the well tt The attributes can also have a different order than described here tt Lines starting with tt ate comments VERSION 1
□
4
The input parameters can be
modified, depending on information available in the input file. Columns can be added or removed in the Import checkshots dialog box using Append or Delete a column in the table buttons.
332 •Condition input data for Seismic well tie
4. From the header info in the lower section of the dialog box, insert the parameters into the spreadsheet at the top of the dialog box. 5. If the Well name is not included in the input checkshot file, assign and verify Connect to trace to the correct well. If the Well attribute is selected, the Connect to trace option is grayed out. 6. Select time and depth datum. 7. If time values are positive in the input file, select the Negate time values checkbox. 8. Click OK to complete the checkshot data loading.
Petrel Geophysics
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Column #
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Zfrom MSL:
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TWT from SRD:
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If a column in the import checkshot file is defined as well name, the option to link a checkshot to a well is grayed out in the import window. Petrel assigns the checkshot to the well with an identical name in the project.
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Default ¡tom date format
29/12/1977
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Header info (first 30 lines): Line
Line Line
Line Line
1: 2: 3: 4: 5: 6:
# Petrel ChecIcShots format VERSION 1 BEGIN HEADER
X Y
Line Z Line 7: TWT Picked Line 8: MD Line 9: Well Line 10: END HEADER Line 11: 1599743.87 -172747.82 0.00 0.00 95.00 "Agate-H6" Line 12: 1599743.09 -172748.18 -100.00 -39.71 195.01 "Agate-H6" 4
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Petrel Geophysics
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OK
A Cancel
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Condition input data for Seismic well tie •333
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Procedure — Quality check checkshots
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It always Is important to quality control the loaded data. In this example, negative time and velocity values reflect errors in the checkshot loading. 1 . Right-click checkshots in the Global well logs folder to open the Checkshot spreadsheet. I *- Input
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Log attributes
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Synchronize MD s Synchronize XYZ's
Insert new attribute
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334 •Condition input data for Seismic well tie
Petrel Geophysics
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2.
Check for negative velocities and TWT.
Checkshot spreadsheet for 'AIICheckShots.es'
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All wells
TVDSS
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TVDSS
1
2
3 4 5 6
7 8
E;
%
9 10 11
12 13 14 15
0.00 100.0C 105 0C 304.9C 504 8C 704 8C 9038C 1101.91 1298.44 1492.04 1687.12 1881.14 2075.74 2273.75 2473.01
Average velocity
TWT
0.00 -39.71 -41.70 -119.30 -194.60 -268.00 -339.10
-5036.69 -5036.10 -5111.56 -5188.051
Sonic log:
At
Time in:
TWT
-5036.70 -5024.45
m
-5152.10 15
9C
-660.60 -720.00 -779.10 -837.30
-5476.32 -5550.75 -5624.66 -5695.24 -5765.95 -5836.88 -5907.11
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Interval velocity
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.59 -5597.94 -5750.44 -5937.42 -6107.47 -6262.40 -6392.81 -6552.38 -6700.89 -6847.33 -6984.90
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Sonic time
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Sonic Int.
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Vel
0.00 8407.16 8405.41 8405.06 8406.60 8366 95 8328.10 8263.58 8139.92 8200.78 8156.95 8181.91 8325.51 8378.31
11.89 12.49 36.27 60.05 83.84 107.63 131.42 155.20 178.98 202.77 226 56 250.34 274.13 297.91 *»*»1
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Correctly loaded checkshot survey parameters (TWT, TVDSS, and velocities) are positive numbers. |
Checkshot spreadsheet for 'AIICheckShots.es'
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TVDSS
Dep*h,n
Average velocity
TWT
1 2
0.00 100 00
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119.30 194.60
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5309.25 544959
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5597 94 5750.44
83 84 107.63
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704.80
7
&:2 2:
268.00 339.10
5259 68 5330.61
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1101.91
408.00
5401.50
5937.42
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9 10
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474.20 537.60
5476.32 5550.75
6107.47 6262.40
155 20 178.98
8263.59 8139.91
11 12
1687.12 1881.14
599.90 660.60
5624 66 5695 24 5765.95 5836 88
6392.81 6552.38
202.77 226 56 250.34 274 13
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2075.74
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14
2273.75
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Petrel Geophysics
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Vel
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Condition input data for Seismic well tie •335
>
I Checkshots editing Checkshot data represents hard facts. You must have good reasons for editing or deleting checkshot data points because they are in situ measured travel times through the sediments.
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By editing one data point, the calculated interval velocity from the point above to the point below is recalculated. An outlier that is removed can give an outlier between the two neighboring points. Q.
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Procedure — Edit checkshot data 1 . In a Function window, display the Interval velocity attribute of the checkshots against Z (or TWT). Use the well filter to display individual checkshot surveys. 0
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IZlBz
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336 Condition input data for Seismic well tie
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| A vef3ce ve/oct/
X Interval ve/odvi WeStiter 0 Agate-H6
4 4 0 Touimaline-5 4 0 Talc-A1 4 0 Quartz-A2 4 0 Mica-A3
Petrel Geophysics
2. Use one of the filter tools from the Window toolbar and select the outliers. ■
5200
5600
6000
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8000
8400
8800
9200
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9600
10000
10400
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I 10800
11200
Select using freehand draw
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Select using ID range on X axis Select using ID range on Y axis
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§ 5200
5600
6000
6400
6800
7200
7600
8000
8400
8800
9200
9600
10000
10400
10800
11200
Interval velocity, [ft/s] Symbol legend Interval velocity vs Z (AllCheckShots cs)
The automatically created filter is stored in the Filters folder in the Input pane. Á
GF 0 Alters folder A S’ 0 User T 0 Interval velocity vs. Elevation depth 1 S 0 System
Petrel Geophysics
Condition input data for Seismic well tie •337
The filtered points are highlighted in the Checkshot spreadsheet ‘i£¡ Checkshot spreadsheet for 'AIICheckShots.es’
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Depth in:
MD
MD 641 642 643
644 645
646 647
1 ¡a
648
649 650
651 652 653 654
7399.94 7599 96 7799.89 7999 93 8199.88 8399.94 8599.93 8799.92 8946 45 65.00 199.98 399 96 599.95 799.93
TWT
All wells
w
Average velocity
2056.20 2098.90 2141.70 2184 30 2226 30 2268.00 2309.10 2349.70 237800 0.00 53.40 130.40 204.80 277.30
7022.50 7059.49 7095.80 7131.80 7167.70 7203.49 7238.58 7272.99 7301.93 5055.43 5137.42 5224.12 5300.61
Interval velocity
8840.93 8876.32 8941.88 9034.63 9114.24 9174.91 9229.78 9705.54 5055.43 5194.29 5376.08 5516.69 5681.25
Sonic log:
At
Time in:
TWT
Sonic time
849.00 870.20 890.54 911.53 932.66 953.22 973.31 994.53 1009 82 0.00 16.03 39.79 63.54 87.30
T
DT
Sonic Int.
Vel 9193.32 8901.97 9338 86 9075.71 8977.52 9243.56 9384.57 8830.98 8980 02
8418.72 8418.72 8418.72 8418.72
-
Well
Drift
179.10 179.25 180.31 180.62 180.49 180.78 181.24 180.32 17918 000 -10.67 -25.41 -38.86 -51.35
Emerald-A9 Emerald-A9
Emerald-A9 Emerald-A9
Dolomite-B1 Dolomite-B1 Dolomite-B1 Dolomite-B1 Dolomite-B1 r.-i
338 •Condition Input data for Seismic well tie
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Emerald-A9
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Deleting the data in the spreadsheet does not necessarily correct the checkshot data because the interval velocity Is calculated between two points. By removing a time-depth pair, a new interval velocity is calculated down to the point below. This can result in a new outlier that must be handled, and so on. Checkshots are hard data points, you must have a good reason to delete this data.
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OK
A Cancel
3. Click the Select using freehand draw button and paint a closed area in the Function window. Make sure that the filter polygon contains some bad points. 4. In the Checkshots spreadsheet, click the Delete selected row(s) in the table button to remove the rows. Click Apply to change the checkshot data. 5. Check the other wells for outliers.
Petrel Geophysics
>
1 Time-depth relationships
<
By doing a thorough quality control, the input sources for the time-depth relationship increase your confidence in the velocity extraction when building velocity models. They also generate good synthetic.
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This also is true for any correction that you make to well tops later or in other velocity models. Q.
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The Time tab in the Wells folder Settings dialog box (Figure 3) contains a list of available sources for the time-depth relationship for all wells.
If more than one object is selected, the list is used in a hierarchical order. A4 Settings for 'Wells' Make logs Style
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Quality attributes
Simulation settings
A
Info
Statistics
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Time
Lateral
Thickness
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Report
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( •/
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OK
Run
| | A Cancel
Figure 3 Setup for the Global time-depth relationship
Petrel Geophysics
Condition input data for Seismic well tie •339
I
9 <
Lesson 2 — Log conditioning The Log conditioning Tool Palette provides tools for editing existing log data to increase the quality and remove deficiencies. The tools are used interactively in the Well section window to modify and condition the log data.
The Log conditioning Tool Palette was designed to supplement the Log editor in geophysical workflows. Edited logs can be saved in the data tree. Interactive editing includes the ability to operate on multiple log zones in depth or time.
Q. 3
Log editing must be done properly. Poor editing results in an inconsistent time-depth relationship and artificial responses in the synthetic, which makes accurate correlation impossible.
Log conditioning: Toolbar access You access the Log conditioning Tool Palette in one of these ways: • On the Seismic Interpretation tab, in the Seismic-well calibration group, click Log conditioning. Petri
Seismic Interpretation
t
• I
Stratigraphy
Iter nanagers
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Seismic Interpretation
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X -section editing
New well section window
Cross-section
340 •Condition input data for Seismic well tie
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Wavelet toolbox
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Seismic well tie
Log conditioning
Well tie editing
Seismic-well calibration
On the Stratigraphy tab, in the Manual logs group, click Log conditioning. Petroleum Systems
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New chart New stratigraphic Chart New column editing chart window Stratigraphic charts
Structural Modeling
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Log New discrete log comment log conditioning Manual logs
Petrel Geophysics
>
•
In Select/Pick mode [P]
right-click on a curve in the
Well section window and click Log conditioning the mini toolbar. <
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SSTVD
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5000
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Petrel Geophysics
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Condition input data for Seismic well tie •341
I Figure 4 shows the options that you can select in the Log conditioning Tool Palette.
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E Tool Palette <
Selection operation ▼
Log conditioning
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Figure 4 Selection options in the Log conditioning Tool Palette
1 2
3 4
5
6
7 8
9
Selection Co-blocking Draw Clip Eliminate Spikes Depth Shift Interpolate Value Smooth Stretch/Squeeze
10
Log extension
11
16
Trend Frequency filter Blocking Undo Redo Save modified logs
17
Clear
12
13 14 15
These algorithms are available for the Seismic well tie process: Co-blocking
Use the blocking on one curve to guide the blocking on another curve.
R
Draw
Ft*
c,ip
Replaces log values with values interpolated between the start value and stop depth. Clip unwanted or unrealistic log values within a selected zone, above or below certain values. Identify and remove spikes from the log.
Eliminate spikes
342 •Condition input data for Seismic well tie
Petrel Geophysics
>
I ll
Depth shift
Vertically shift a log. Applied only for the entire log.
Interpolate
Replace the values of a log in a selected zone by the linear interpolation of the first and last values. Apply a general smoothing algorithm to log values.
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? Q. 3
|
Value smooth
Stretch/squeeze
Log extension
Trend
ST
Frequency filter
Blocking
Clear
Interactively reposition log depth values inside a segment, preserving or deforming the log outside the selection. Vertically extend, with a predefined fill value, the top of the log to a shallower depth or the bottom of the log to a deeper depth. Identify, compute, and remove trends created by compaction, thermal, or other depth-related phenomena. Analyze and filter the frequency spectrum of the log. Additionally the spectrum of a seismic trace at the well position can be displayed as guidance. This filter can be applied only to a single log at a time. This operation is available only if the well contains a defined Time-Depth Relation (TDR). Automatically block well logs. This can be useful for reducing the resolution of the log to a coarser seismic resolution, prior to generating synthetic seismograms.
The Clear option removes all operations and selections executed on the logs in log conditioning.
Edited logs can be saved to the Petrel data tree.
Petrel Geophysics
Condition input data for Seismic well tie •343
>
I Log conditioning Tool Palette: Despiking
<
Despiking is important, especially when performing the seismic well tie process using sonic logs. The frequency content of the sonic is much higher than the frequency of the seismic.
Removing high frequency variations from the sonic to better match the seismic resolution aids their comparison and avoids error accumulation. The spike value errors accumulate down through the well when integrating the sonic values. Q.
jo
The original and edited logs can appear simultaneously in a track of a Well section window. By default, the horizontal scale is different, ranging from the minimum to the maximum values of each log. As a result, it can be necessary to adjust the scales so that they are the camo fnr hnth Innc Thic aHmctmont ic rlnno in the Wall Sartinn
>
Procedure — Despike a Sonic log 1. Display a Sonic log in the Well section window. (You also can display other logs to help you better select the section of the log for despiking.)
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m >
, right-click the Sonic log curve 2. In Select/Pick mode[P] and click Log conditioning sift in the mini toolbar. - |jf Well section term - § ft | | &[£)l SSTVD $ÿ> Copper-6 [SSTVD]
z
v:
1:850 100.58
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Sonic us/ft 129.38 0.42
4336 2
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4450 :
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Sonic (Continuous well log) Show the selected item in tree
4500
4550 -
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Send to Studio
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Edit global color table
A
Delete . . .
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s
4600
4
4ft Retrieve from Studio
|{=1 (j=) (jj1
Copy as derived log
1ÿ
Add to global template
Copy continuous well log (data only) Make log(s) dynamic
Add to local template
Log set 4650 -
Guru
CTH
n
i
i i-
H
3. To select a zone of interest in the log, click Selection When you open the Log conditioning Tool Palette, it already is enabled by default.
ES3
Tool Palette
E: Selection ▼
»
Log condit'oning
[T
R ft Sx II
Petrel Geophysics
x
,> n
r
•? ST H '
um Condition input data for Seismic well tie •345
4. Click the log track and drag. Depth limits are displayed as well as the log and well names. Double-click to select the whole track. Co;
<
:
.
'
■
I CALI in
Sonic
1850 100.58
us/ft
129 38 0 42
P
4336 2
>
. -t
-
4400
[•] 4450
4500
T
0
> >
c
4550
Selection
* Log condit oning
3«
R ft. 5* II #
S*
-i
I 5
•?
¥H -
U
Domain
Start
End
Log
SSTVD (ft)
4418.12
4569.41
Sonic
Well Copper-6
Enable Delete
@1
@
0
-
4700
f 4750
-
4801
1.
5
Q
346 •Condition input data for Seismic well tie
c 1
Petrel Geophysics
5. In the Log conditioning Tool Palette, click the Eliminate spikes button. 6. Select parameters and click the Eliminate spikes button. <
>
1 496
I ilCALl 3 5T
4390 4400
4420
4440
[•] 4460
4520
4540
4560
■
7 ;
▼
umber of standard deviation:
Log condit oning
\
I?
a
Spike detection options:
* Eliminate spikes t ?
i
- ■? S* -
UÓ
Spike analysis window:
1 46
-G
162
Replacement method: Interpolate
▼
samples
[[Eliminate spikes|
4640
4661 1
Petrel Geophysics
Condition input data for Seismic well tie •347
7. Click Save modified logs and click Apply. Now, you can modify the name of new log. Copper-6 [SSTVDf SSTVD 1 495
<
'l 00 58
(
Sonic us/ft
129.38 0 42
CALI in
>
ifeonc
4390
4400
4420
4440
[•] 4460
i
I
0
4500
<
J
% s
4520
>
4540
4560
4580
%
Tod Palette
J ▼
Log condit oning
/? 4640 ■;
4661.2;
a
Save modified logs:
Save modified logs
>x ll t ?
1
348 •Condition input data for Seismic well tie
4
r
-¡> ST H
-
x
U in
Output for Sonic on Copper-6:
0
Sonic (new)
| Save all checked logs
Petrel Geophysics
I The new log appears in the Global well logs folder in the Input pane. •
<
““ Input
▼
@ Wells ' t @ Qobai weSbgs * [>
®S'
*
X
>
Log attributes
BI0 CALI
5 □ CILD Rn □ CILM
Q.
Rs □ CSFL O □ DPHI
P □ DRHO
Jo
At 0 Sonic Y □ GR Rp □ ILD Rn □ ILM •n □ NPHI □ PHIT P □ RHOB Rp □ RT Rxo □ SFLU 7>+ □ SP Fra □ VCL Rn □ SN
Petrel Geophysics
Condition Input data for Seismic well tie •349
I Exercises — Condition input data for seismic well tie In these exercises, you learn to import and quality check the checkshot data and condition the well data to prepare it for Sonic calibration which will be later used for synthetic generation. Exercise workflow 1. Import checkshots. 2. Make a well section. 3. Quality control and edit well logs.
Q. 3
n
0
Exercise 1 — Import checkshot data for a single well 1. Right-click the Wells folder in the Input pane and select
You can find the input files in Data import\ Well input data\ Checkshots.
.
Import (on selection). 2. Find the input file in Data import\Well input data\ Checkshots. Remember to set the Files of type to Checkshots format (ASCII) (*.*). 3. Select the Diamond_ 14.cs file (do not select the AIICheckShots.cs file) and click Open.
Columns can be added or removed in the Import checkshots dialog box using the Append or Delete a column in the table buttons. Each file must be attached to the correct well trace (done automatically here). It is possible to set different depth and time datums, depending on the input.
350 •Condition input data for Seismic well tie
Petrel Geophysics
Match the parameter settings with the header information section in the lower part of the window. Make sure that Number of header lines is set to 2 and the Negate time values check box is selected.
4.
<
[\] Import checkshots: Diamond_14.cs
>
1ÿ1
sida Column #
2
1
>1
Attribute TVD Attribute name TVD Attribute type Continuous feet Unit
%
©
A
Connect to trace:
TWT TWT Continuous millisecond
Diamor>d-14
▼
Number of header lines: 2 Undefined value:
Diamond_14cs
Well name:
-999
a
Depth Depth datum:
<
T
MSL
"£
SRD
Zfrom MSL:
▼
[°
ft
(Ó
ft
a >
Negate Z vak
Time Time datum:
Zfrom MSL:
[7] Negate time values
TWT from SRD:
yj
ms
□ Replai
ft/s
Date
a a
(§) Default © Custom date format
3DE 29/12/1977
Time Zone
E
(UTC+01:00) Brussels. Copenhagen, Madrid. Paris
▼
|7] DST enabled
Header info ffirst 30 lines):
Line Line Line Line
1: Diamond-14 Checkshots 2: TVDSS feet TWT ms
A
□
3: 0.0000 0.00 4: 81.990 32.60
4
V OKforaB
] [ V OK
|
Cancel
5. When satisfied with the parameter selection, click OK. 6. Click OK in the Input data dialog box that appears.
Petrel Geophysics
Condition input data for Seismic well tie •351
7. In the Global well logs folder, locate the newly imported Diamond_14.cs object. 8. Right-click the object and select Spreadsheet. •
<
*
Input
-
w
Q X
>
0 Wdls
t □ Gbba/wefbgs Log attributes
IS □ CALI t □ CILD
R« □ CILM R$ □ CSFL
□ DPHI
[m
P □ DRHO At □ DT Y □ GR RD □ ILD R« □ ILM *n □ NPHI □ PHIT
%
<%«
P □ RHOB RDD RT R*o □ SFLU 7* □ SP Fra □ VCL R« □ SN
<
>
Diamond_14.i
Settings
.
Import (on selection) .. Export object
Efl.it global color table A
Delete
...
Spreadsheet
|=) l> " é
f f
•
1
Copy as derived log or log template Collapse (recursive)
Expand (recursive)
Synchronize MD s
Synchronize XYTs Insert new attribute
Convert to interpretation
Ly Guru
352 •Condition input data for Seismic well tie
Petrel Geophysics
<
9. Change the Depth in field to 7VDSS from the Depth in list at the top of the spreadsheet. In the Checkshots spreadsheet dialog box, all grayed out columns are calculated. Average velocity and Interval velocity values are derived from the input time-depth pairs. Sonic time and Sonic Int. Vel come from the input sonic log. Drift is the difference between the two data sources. All checkshot data in Petrel is referenced to TVDSS (that is, referenced to MSL).
The first two columns can be edited if necessary.
>
|
Checkshot spreadsheet for 'Diamond_14.cs‘
M) %
¿
Well:
ED El El® TVDSS
2 3
4 5
6 7 8 9
10 11 12 13 14 15
16 17 18
19
81.99 281% 481.95 681.94 881.93 1081.91 1281.90 1481.90 1681.89 1881.89 2081.80 2281.80 2481.80 2681.80 2881.80 3081.80 3281.80 3481.70
All wells
w
TVDSS TWT
32.60 110.30 185.30 258.20 329.10 397.90 465.30 530.80 594.60 657.20 718.50 778.60 837.50 895.40 952.20 1008.00 1063.20 1118.00
Average vek>city
5030 06 5112.60 5201.83 5282 26 5359.65 5438 10 5509 99 5583.65 5657.21 5726.99 5794.85 5861 29 5926 69 5990.17 6052 93 6114.68 6173.44 6228 44
Sonic log
At
Time in:
TWT
Interval velocity
5147.23 5333.07 5486.69 5641.47 5813.37 5934.42 6106.87 6269.28 6389.78 6522 35 6655.57 6791.17 6908 46 7042.25 7168.46 7246.38 7295.62 7220.22
DT
Sonic time
10.82 37.23 63.63 90.03 116.43 142.84 169.24 195.65 222.05 248.46 274.85 301.25 327.66 354.06 380.47 406.87 433.28 459.67
CD
||
- B s® a Sonic Int.
Vel
7574.47 7574.48 7574.48 7574.48
7574.47 7574.47 7574.48 7573.90 7574.30 7574.20 7574.27 7574.31 7574.31 7574.39 7574.05 7574.12 7574.38 7573.65
Drift
-5.48 -17.92 -29.02 -39.07 -48.12 -56.11 -6341 -69.75 -75.25 -80.14 -84.40 -88.05 -91.09 -93.64 -95 63 -97.13 -98.32 -99 33
✓ OK
V Apply
Well
Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14 Diamond-14
=
7< Cancel
Deleting data in the spreadsheet does not necessarily correct the checkshot data because the interval velocity is calculated between two points. By removing a time-depth pair, a new interval velocity is calculated down to the point below, which can result in a new outlier. Checkshots are hard data points; you must have good reasons for deleting any data. 10. Scroll down the spreadsheet and observe the available data. 11. Save your project.
Petrel Geophysics
Condition input data for Seismic well tie •353
I 0 <
Exercise 2 — Import and quality check checkshot data for multiple wells When the quality check and edit is finalized, the checkshots can be used to calibrate sonic logs. You also can use them to establish time-depth relationships directly in wells. 1. Right-click the Wells folder in the Input pane and select Import (on selection). 2. Find the input files in the Data import\Well input data\ Checkshots folder. Remember to set the Files of type to Checkshots format (ASCII) (*.*). 3. Select the file AIICheckShots.cs and click Open. 4. Check the parameters in the upper part of the Import checkshots dialog box against the first 30 lines of the header
Q.
jo
•
354 Condition input data for Seismic well tie
Petrel Geophysics
>
R] Import checkshots: AllCheckShots.cs
1ÿ1
si a a Column #
<
Attribute Attribute name Attribute type
1 X
X
4
5
6
z
TWT
MD
Well
Continuous File CRS unit
Well Z TWT MD Text Continuous Continuous Continuous millisecond feet feet
MCheckShots.es
Well name
Undefined value:
Depth datum:
E:
a
-999
a
Depth
PH
>
Diamond-14
Connect to trace:
®
3
Y
Continuous File CRS unit
Unit
2
Y
MSL
Zfrom MSL:
0
ft
SRD
Zfrom MSL
0
ft
TWT from SRD:
0
ms
Negate Z values
Time
“£
Time datum:
%
Negate time values
□ Replacement velocty
a
ft/s
Date
a a
(3) Defauft
©
Custom date format
29/12/1977
Time Zone
a DST enabled
(UTC+OTOO) Brussels. Copenhagen. Madrid. Paris
Header info first 30 lines): Line
Line Line
Line Line Line Line Line Line
*
1: Petrel CheckShots format 2: VERSION 1 3: BEGIN HEADER 4: X 5: Y 6: Z 7: TWT Picked 8: MD 9 Well
Line 10
END HEADER
Line 11 Line 12
1599743.87 -172747.82 0.00 0.00
95.00
"Agate-H6"
1599743.09 -172748.18 -100.00 -39.71 195.01 "Agate-H6"
4
V OK for all
Petrel Geophysics
✓ OK
|
A Cancel
Condition input data for Seismic well tie •355
5. Click O/Cto import the checkshot data file. 6. Click OK for All on the appearing Input data dialog box. 7. In the Global well logs folder, find the AIICheckShots.cs object. 8. Right-click AHCheckShots.es onú select Spreadsheet. 9. On the Home tab, in the Insert group, click Window, then click Function windowto insert a new function window.
<
File
G&G
✓ai
Perspective
Home
¡a Tool
Stratigraphy
Seismic Interpretation
<5 B t ai Inspector
palette
Players
Visual filters View
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Petroleum Systems
Decision Support
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Full screen
Panes
Reset
»
layout
Window
ETfl
[1
>
Structural M
a
~
Object
Folder
r
a Peti
2D window 3D window
Function window
[ja]
Hjstogram window
HD
Interpretation window
[jjg]
Intersection window
¡I
Map window
1551
Plot window
|5j?| [ÿ1
Tectonic stress window
fl
Charting window
Stereo net window
Well section window
lornado plot window
El
QI crossplot window
[¡51
Stratigraphic chart window
Geotime window
1 0. Crossplot the Interval velocity vs. Z attributes for AIICheckShots.cs by selecting them in the Attributes subfolder. The display can be changed on the Style tab in the Settings dialog box for the data.
356 •Condition input data for Seismic well tie
Petrel Geophysics
11 . Expand the Well filter and use it to display checkshot data only for the Albite-F1 well. m-V.-'gL-*.*.
5200
5400
5600
5800
6000
6200
6400
6600
6800
7000
7200
7400
7600
7800
8000
8200
8400
8600
8800
MOO
9200
9400
9600
9800
<
I-
■
1'
•i ■i
iSI
* 'ÿ$ 13
•
N
AJICheckShols.es 0 Attributes
i
Z\®z
ti
D TWTpickcd □ MD Wd O Average velocity tv ® Interval velocity Welder □ Agate-HG 0 Abile-Fl D Amethyst -3
HI>I 0
1 0
Xn
!ÿ
a
AA
5000
■
■
4
i-
<
>
■
a!
5200
5400
5600
5800
6000
6200
6400
6600
7000
6800
7200
7400
7600
7800
8000
8200
8400
8600
8800
9000
9200
9400
9600
>
9800
Interval velocity, [ft/s] Symbol legend Interval velocity vs Z (AllCheckShots cs)
12. Use the Select using freehand drawtoo\ and paint a closed area in the Function window. Make sure that the filter polygon contains some bad points (outliers). lab diBHZ 4400
4800
5200
5600
lift
f Iftft
QB•
Select using 2D rectangle
H'du-iT1 D'EH-
]-
Select using freehand draw
7200
7600
8000
- Bi-a8400
A
8800
| 9200
9600
10000
Select using ID range on X axis Select using ID range on Y axis
I-
É §
N*“
4400
6000
6400
6800
7200
7600
8000
9200
10000
Interval velocity, [ft/s] Symbol legend Interval velocity vs Z (AllCheckShots cs)
Petrel Geophysics
Condition input data for Seismic well tie •357
13. In the Checkshot spreadsheet, click Delete selected row(s) in the table to remove the row and click Apply to change the checkshot data. 14. Check the other wells for outliers.
<
l
Checkshot spreadsheet for 'AIICheckShots.es'
m
□MB MD 1370
6619.90
1371
6819.90 7019.90 7219.88 7419.90 7619.91 7819.86 8019.83 8219.84 8419.85 8734.18 49.00 199.99 399.97 599.96 799.94 999.93 1199 92
1372
1373
E!
1374
ft
1376
1375 1377 1378 1379 1380 1381 1382
1383 1384
1385 1386 1387
¿
Well: Depth in:
All wells
MD
TWT
1896.50 1943.10
1989.50 2035.50 2081.10 2126.30 2171.20 2215.70 2259.80 2303.60 2368.00 0.00 59.70 136.60 211.30 283.80 354.40 423.30
Average velocity
6885.59
6926.07 6965.46 7004.48 7043.19 7081.59 7119.32 7156.83 7194.18 7231.03 7299.83 5058.29 5138.65 5214.96 5292.04 5366.42 5437.85
Sonic log:
At
Time in:
TWT
Interval velocity
8573.66 8614.93 8691.77 8771.52 8849.59 8906.10 8986.87 9070.43 9132.65 9760.85
5058.29 5201.04 5354.48 5516.69 5665.44 5805.22 5942.94
DT
Sonic time
783.99 805.64 827.74 849.50 871.57 893.71 915.90 937.71 959.58 981.02 1015.83 0.00 17.00 39.51 60.98 82.20 103.32 12445
Sonic Int.
Vel 8612.32 9228 09 9043 39 9187.30 9061 92 9032 33 9011.47 9165.25 9147.18
9328.77 9027.72 8882.53 8882.53 9315.09 9423 42 9470.61 9464 33 ✓ Apply
CD
[I B~||w£3w|
- di ss s Drift
-164.26 -165.91 -167.01 -168.25 -168.98 -169.44 -169.70 -170.14 -170.32 -170.78 -168.17 0.00 -12.85 -28.79 -44.67 -59.70 -73.88 -87.20 ✓ OK
Well
Albite-F1 Albite-FI Albite-FI Albite-FI Albite-FI Albite-F1 Albite-FI Albite-FI Albite-FI Albite-FI Albite-FI Turquoise-2 Turquoise-2 Turquoise-2 Turquoise-2 Turquoise-2 Turquoise-2 Turquoise-2
□
A Cancel
15. Save your project.
358 •Condition input data for Seismic well tie
Petrel Geophysics
>
<
>1
Exercise 3 — Condition logs The Log conditioning toolbox provides a number of tools for editing existing log data to increase quality and remove deficiencies. The tools are used interactively in the Well section window to modify and condition the log data. These tools also allow you to save the edited log
>
in the data tree. 1. On the Home tab, in the Insert group, click Window, then click Well section window to insert a new well section window. Home
%
0
ive
*« Tool
Seismic Interpretation
Stratigraphy
E ir ffi
Inspector
Players
palette
Visual filters
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Petroleum Systems
Decision Support
Structural Modeling
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Full screen
Panes »
Reset layout
View
Window
Object
Folder
Property Model
§i Petrel Studio
Studio
Impor
file ,
•
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Search
2D window
Mana
ETH ID window ] Function window [j|i] Hjstogram window
(ID [*£l
I
Interpretation window
Intersection window
MaP window
[tjg] [jfe]
Stereonet window
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@
Charting window
Plot window
[ÉH Well section window
[y| Tornado plot window [jÿ| QI crossplot window [51 Stratigraphic chart window
[|¿5
Geotime window
2. Click OK in the Select new well section window settings dialog box. R] Select new well section window settings
n .j
tÿ-1
X-section
'• Create new x-section:
a a a a a
X-section 1
s 0
Template
ü '• Create new template
©
¡Elet
Use existing template:
section ti
l-itl
Well section template 1
/‘ppiy to all new well section windows
Show template settings
[V Petrel Geophysics
OK
] [ÿCancel Condition input data for Seismic well tie •359
3. Display the well Diamond-1 4 found from the Wells folder. 4. Open the Global well logs folder and display GR, CALI, RHOB, and DT. <
i*ÿ Input
-
x
9
■
ft
'
M Vj Wells
i|-0 Ghbahvelhgt I*
¿51
1
I8I0 CALI
& □ CILD
[•]
4200
-j-
Rs □ CSFL
4300 -i
At 0 DT
4400
P □ DRHO
Y
a
GR Rp □ ILD
=
4600
RD □ RT
4700 -j
£+ □ SP
4800
p a RHOB
R«o □ SFLU
Fra □ VCL Rn □ SN
4900
Diatnond_14.cs AJICheckSh0t3.cs
t>
gAPI
- E, l~t
S5 Well section tern
I:' us/ft 303.8C
RHOB
207.751ÿ010
2ÁA\ 1 4380 »cm3 2 6620 |'l 4 90
m
f
[bblVUJ
1
1
c
t
4500
*ii □ NPHI <%, □ PHIT
P
)iamond-14
t
Rn □ ILM
0
286915 66
4131.8;
R„□ CILM
*
:-=ÿ
Hz-;
Log attrfoutes
SSTVD
J
> \
I
V
r ?
-
;
.
5. On the Well Section tab, in the Cross-section group, click if-t
a
Well correlation
File Well section tern
Stratigraphy *
Template settings
correlation!
New template Templates
ism
n
v*
____
Petroleum Systems
Seismic Interpretation
1 snow vertical tracks
Cross section
|
Show cell boundary
Visualization
Decision Support
Set production chart mode
Structural Modeling
Domain;
|H
Well correlation
-r’
SSTVD '
•
Window settings
5
. The Tool Palette opens.
Property Modeling
_4®. ¡¡¡¡¡ Scaling
|l|J
view all
Fracture Modeling
4*-
Equalize scales
ww Sync
View entire well Vertical scaling
6. Color fill logs by clicking Curve fill correlation Tool Palette.
360 •Condition input data for Seismic well tie
Production
rolling
Well Design
Relative 50000
Sync
j scaling
[a| Insert (2 Show ¡§ Mane
Horizontal scaling
in the Well
Petrel Geophysics
>
0 Diamond-14 SSTVD GR CALI 1:2869 5.66 gAPI 207,75 -0.10 in 2.44 Caliper ima rav
SSTVD] RHOB
'~ 43.S0 3.cm3 2.6620
DT 14.90 usffl 303.80
lensitv
4200
Sonic
l
4131.8: 4
4300
4400
4
4500
T
>1
4600
IT
0 4700
_¿j Q 3D grid 4800
_
Completions design Edit fault properties
Facies
4900 ■:
'Á 5000 -i
__
@
<M[•,;
T= 1 oo4
Fault model Geobody interpretation
•fjjj Z] Geomechanics tools 5100 c
¿
Geopolygon editing
__
Log conditioning Mesh editing
5200 c
Palette
Select Wel correlation
33 » X
ipffeas”!
¥
['
-s
Microseismic Pad editing
5300
Point editing
Polygon editing
5400 c
Prestack seismic 5500
Í [2 i
__ Z}
~
Seismic interpretation
Seismic well tie
5600 c 5700
QI tools
-IB{
Stratigraphic chart editing
n Surface editing_
!S 3 Well correlation 5800
Well design
-
IjS 5900
6000
6128.8a
Petrel Geophysics
X-section editing
F
I Condition input data for Seismic well tie •361
switched on, click on a curve 7. With Select/Pick mode [P] in Well section window and then click Adjust color table in the Quick Access toolbar to refresh the color fill of the curve.
<
□•[!]«
Siy D
>
1SI =
8. From the Well section Window toolbar, click Template
1=1
settings . From here, you can adjust the template and curves for suitable display. 0
|Q
fe
SSTVD
•
Well section ten
-
I,D Undef
•
fif®*
!
.
M- Retake
50000
■
B-B* Q
- HE'S H
t
9. Set the log curve values of GR and DT to 0-200 and 30-300, respectively, to display the logs better in the Well section window. [ÿ]
S3
Settings for 'Well section template 3'
0 Info”! [{§}
Well section template
Template objects
ns B m
B
r@Y Eü
i3HTro
toÿCALI
É
Hi
Template objects
n■@0
Index track
¿ÿÿVIA GR
0Y
Co
a
Normal
|_Both
@P RHOB
-
.
— TSatMl Borehole markers wjua
a
Objects settings
O
Into
[ÿ¡ Definition| fTf Umitsj
0 Min value:
GR
0¿CALI 0gjCAU RHOB
-
200
□ Wrap
¿
Vertical tracks (5)
E
Ü.
0
m Max value:
@flt DT
la-
1]
0 Min value
Borehole markers Background Deviated tracks (0)
E)
fa
Qg} Definition )[ÿ] Limits! V Style
Info
Direction:
RHOB
L-gjp RHOB 0j£. DT
a
Objects settings
0
@ (] Index track -
El
U-
_
| Vertical tracks (5)
Style
d
30
@j Max value: 300 Direction
E
Wrap:
Normal
| Both
D= Background Deviated tracks (0)
*/ /tpply
362 •Condition input data for Seismic well tie
]
■/ OK
A Cancel
|
Petrel Geophysics
10. In Select/Pick mode [P]
, click
on a curve in Well section
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11 . Identify the zones with spikes on the sonic log.
12. In the Log conditioning Tool Palette, click Selection
Petrel Geophysics
Condition input data for Seismic well tie •363
13. Click and drag the mouse to select an area around spiky sections in the DT track. If you double-click the track, the entire log is selected.
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spike
364 •Condition input data for Seismic well tie
P* .
Petrel Geophysics
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Note how the selected area of study can be affected by changing the parameters (Number of standard deviation, Spike analysis window, and Replacement method). 15. Continue until you are satisfied with the level of removed spikes.
I to remove the spikes.
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I Eliminate spikes
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17. After reviewing the complete sonic log section in line with key logs and despiking where necessary, click
Save modified logs Palette. Petrel Geophysics
E3 in the Log conditioning Tool Condition input data for Seismic well tie •365
1 22. Select the Min value and Max value check boxes and enter 30 and 300. [BJ
Settings for ’Well section template 3'
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Well section template -
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Direction:
Normal
□ Wrap:
Both
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- 0ÿ
DT Sonic Despked
l2)At Borehole markers Background Deviated tracks (0)
23. On the Style tab, choose Selected from the list next to the color section. 24. Choose a different color for Sonic Despiked and click Apply. 25. Highlight the Sonic Despiked log from the object list on the left side of the dialog box. Move it under the track that contains DT by using the blue arrow.
Petrel Geophysics
Condition input data for Seismic well tie •367
I 26. Remove the empty track, click Apply, and click OK. |S I»
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27. Save your project.
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Review questions
• •
What are the main quality control steps for importing checkshot data? Name five major functionalities in the Log conditioning tool?
Summary In this module, you learned about: • loading and quality controlling checkshot data • defining time-depth relationships • using the Log conditioning Tool Palette
368 •Condition input data for Seismic well tie
Petrel Geophysics
I Module 7 — Sonic calibration <
In this module, you learn how to use sonic log and checkshot data to create a consistent time-depth relationship. In addition, you are
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presented with some theoretical background about sonic calibration. jo
Learning objectives <
After completing this module, you will know how to: • calibrate a sonic log • select input data and parameters • define knee points and outputs
Petrel Geophysics
m
Sonic calibration •369
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Lesson 1 — Sonic log calibration Calibrating the sonic log corrects the log velocities to time-depth data (typically checkshots) and accurately hangs the sonic log in time. A time-depth relationship can be generated from the calibrated sonic log. It is used as the preferred time-depth relationship for the well of study.
>
You perform calibration by increasing or decreasing the sonic slowness values slightly over sections of the log until the integrated sonic log travel times match the times derived from the checkshot survey. The mechanism used to control this process is termed Drift Curve (Figure 1).
Q. 3
Drift can be computed at every depth level and is defined as: Drift = checkshot time - integrated sonic time (Tcheckshot- Tlog)
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1 2 3
4 370 •Sonic calibration
DT Sonic TD curve Checkshots Drift: Sonic T - checkshots Petrel Geophysics
I If the drift curve is positive, the checkshot travel time is longer than the integrated sonic travel time, meaning that the sonic log is too fast. If the drift curve is negative, the sonic log is too slow. <
Q.
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Use calibration to define a drift curve that goes through the checkshot data that corrects the sonic log to the known travel time values that are derived from the checkshot data. The result is a calibrated sonic log (Figure 2).
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There are two ways to apply the necessary corrections: • The differential correction method uses multiplication to shift the sonic log to higher velocities. The correction is applied as a velocity-dependent percentage, so that larger corrections are applied to the lowest velocity sections. This correction is based on the assumption that low velocity sections of the log are prevalent in poor borehole conditions and contribute heavily to transit time errors. • The linear correction method uses simple addition to shift the sonic log to lower velocities. This correction is based on the assumption that high velocity sections of the log are in better borehole conditions and make up only a small part of the transit time errors overall.
In Figure 2, the updated TD is converted to the calibrated sonic log DT_Calib.
Petrel Geophysics
Sonic calibration •371
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Figure 2 Drift curve is added to the sonic TD curve; Sonic log + Drift curve = DT_Calib
Procedure — Calibrate a Sonic log using the SWT dialog box 1. File
On the Seismic interpretation tab, in the Seismic-well calibration group, click Seismic well tie. Home
Stratigraphy
'99 Managers
3
Seismic (default)
Houston_Restorat
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As a minimum for the sonic calibration, a sonic curve must exist in the well. If one or more objects related to time-depth information (such as checkshots) are associated with the well under study, they are available from a list in the dialog box.
•
372 Sonic calibration
Setup
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Seismic Interpretation
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well tie
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Wavelet toolbox
§§
Log conditioning
if E Insert
Well tie editing
Seismic-well calibration
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Seismic interpretation
2D/3D interpretation
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The Seismic well tie dialog box opens.
Petrel Geophysics
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2. In the Seismic well tie dialog box, select Sonic calibration as study type and select the well to use. 3. Select the default sonic calibration template. 4. Select the parameters on the various tabs in the dialog box. (These tabs are discussed in the next section.) 5. When you are satisfied with the parameters, click OK.
If no checkshots exist for the well, a checkshot object can be dropped in from another well. In this situation, you also can use a sonic or velocity log as TDR.
■pll Seismic well tie Q.
Seismic well tie 9
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Hints (Study 1) Diamond-14 Sonic calibration
Create study:
£ O Edit study: Type of study:
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Sonic calibration
Output
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| Datuming | Time-depth | Options | Statistics
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Sonic calibration default template
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At Sonic log:
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O Drop from other well
A Well section window opens where you can calibrate your sonic log (discussed later in this lesson).
Petrel Geophysics
Sonic calibration •373
I Input tab The Input tab (Figure 3) in the Sonic calibration study controls the input of sonic logs, checkshots, and the time-depth relationship (TDR). Checkshots are the most common TDR used; however, if this data is not available, integration of either the sonic and velocity logs is supported. The input options are available according to the selected well.
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Input
[ Output | Datuming | Time-depth |
Options
| Statistics | Track manager
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Parameters:
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At Sonic log:
I I
TDR:
[ÿ]
At Sonic Despiked Diamon
▼
»
□ Drop from other well
Jo Figure 3 Input tab in the Seismic well tie process dialog box
Sonic log: Input sonic log that is calibrated. Velocity logs also are accepted. 2 TDR: Name of the TDR (usually a checkshot) that is used to calibrate the sonic log. If no checkshot is available for the well, you can drop in a different one from another well.
1
374 •Sonic calibration
Petrel Geophysics
>
1 Output tab
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On the Output tab (Figure 4), you can control the output logs from the sonic calibration study. The Output tab has these options: • Calibrated sonic • Time-depth relationship (TDR) • Integrated sonic • Drift curve/TcmTI • Knee points • Knee curve • Residual drift Input | Output A
The Auto save option automatically saves any changes made to the output during the process.
| Datuming I Time-depth I Options I Statistics Track manager
) Calibrated sonic
Calibrated sonic:
A
Calibrated sonic
□
O Auto save
® Time depth relationship (TDR) TDR name:
Calibrated TDR Sample interval:
16 40
; ft
4IB
□ All samples
I’/; Autosave |
|Set as active TDR|
(v) Integrated sonic
® TcmTl (v) Knee points v
i
Knee curve
© Residual drift Figure 4 Output tab in the Seismic well tie dialog box
Petrel Geophysics
Sonic calibration •375
>
I The time-depth relationship (TDR) derived from the calibrated sonic can be used to convert the wells in time. In the Settings dialog box for the Wells folder, on the Time tab (Figure 5), there is a priority list for sources to establish TDRs. All possible velocity data sources that can be used to establish a TDR in the project are listed there.
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For any given well, the TDR is established from the top of the list using only the selected objects (with a check mark). If the data object does not exist for the well, the process goes to the next object down. Q.
To rearrange the priority list, click the item that you want to move and use the up and down arrows to reposition it. Select the check box next to the objects to include them as a possible TDR source (blue check
3
mark). AA *
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Settings for 'Wells'
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Figure 5 Time tab in the Settings dialog box
The From shared checkshot option uses data from one well to establish time-depth relationships in other selected wells. Activate the option, choose a well from the Well filter of the available checkshot item, and insert “v* it into the dialog box.
The Manual adjustment option allows you to adjust the TDR manually based on Well tops. 376 •Sonic calibration
Petrel Geophysics
>
I When you click on Set as active TDR in the Seismic well tie dialog box, the output TDR derived from the calibrated sonic log is selected automatically on the Time tab only for the well of study. <
Q.
It is not applied to the other wells. It overrides the global settings for this well only.
>
Sample interval When saving or autosaving the time-depth relationship (that is, saving with continuous generation), there are options to set the sample interval of the time-depth relationship.
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Datumingtab Datuming is of key importance. By default, the Seismic well tie process picks up the project datum and kelly bushing of the currently used well. The kelly bushing (distance from Mean Sea Level) is returned as Elevation of sonic log depth datum. These options are used only if the project datum and Seismic Reference Datum do not coincide with Mean Sea Level.
Figure 6 shows the marine datum options on the Datuming tab. Figure 7 shows the land datum options on the Datuming tab.
Petrel Geophysics
Sonic calibration •377
Input
I
I
| Time-depth |
Output Datummg
Options
| Statistics ¡
Track manager
U
0 Land datum 9 Marine datum Checkshot
Log depth datum (KB)
depth cfetvm
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v Vw Vb
Datum elevation
1 0
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Checkshot time-zero (b):
0 00 ft
@| Use SRD
Output time (TWT) (c):
0.00 ft
□ Use SRD
Above mean sea level: Elevation of sonic log (a):
118 00 ft
Replacement velocity (Vr):
4862 20 ft/’s
Velocity (Vw):
Velocity (Vb):
Seabed
a a
0.00 ft 4862 20 ft's
a
Below seabed Depth of seabed (from MSL) (e):
_
a
Water layer
Elevation of water surface (d):
>
Tme datvm (SRD)
0 00 ft 4862 20 ft's
Figure 6 Options for Marine datums on the Datuming tab
378 •Sonic calibration
Petrel Geophysics
I Input
| Output)
Datuming
| Time-depth | Options | Statistics )
Track manager
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| © Land datum | Marine datum Cheefcjhot
,log depth datvn (KB)
depth datum
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Datum elevation
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ii
Checkshot time-zero (b):
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g]UseSRD
Output time (TWT) (c):
0 00 ft
□ UseSRD
Above ground surface
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Elevation of sonic log (a):
118.00 ft
Replacement velocity (Vr):
486220 ft/s
Weathering:
Velocity (Vw):
118 00 ft 7874.02 ft/s
a
Below weathering: Elevation of the base of the weathering (e): Velocity (Vb):
>
a
-
Elevation of ground surface (d):
a
118 00 ft 7874 02 ft/s
Figure 7 Options for Land datums on the Datuming tab
Datums and replacement velocities The process of bringing sonic log velocities into agreement with seismic velocities does not, by itself, guarantee a correct depth-time relationship. The logs also must be placed in the correct position relative to the seismic data before integration using datums and replacement velocities.
In the context of sonic log calibration and well-seismic tie, a datum is defined as the elevation at which a property is set (typically) to 0.0, in either the depth or time domain. The location of the datum is coaxial with, or directly above, the wellbore trajectory.
In most cases, a datum consists of a single scalar value. However, in some cases, a datum is derived from a surface with either a constant or variable elevation, which can be important when dealing with deviated wells (such as ground surface or water bottom elevation). Petrel Geophysics
Sonic calibration •379
I Replacement velocities, when used, cause static (vertical) shifts to seismic and other time domain data (checkshots, VSPs). These velocities bring a specific point in time (or some time domain surface) into alignment with some common elevation feature. This feature can be real (ground level) or arbitrary (3,000 m above MSL). These velocities can be constant (air-ground surface replacement velocity) or spacevariant (ground surface-based weathering layer replacement velocity).
<
Datum errors are a common cause of confusion when working with well and seismic data. A clear understanding of the datums is required to ensure that all necessary shifts are applied and that all data objects are properly aligned.
Q. 3
Alignment errors can result in mis-ties or erroneous phase estimations, which is true particularly when working with VSP data on land. The VSP acquisition and processing reports are crucial to understanding mis-ties and inconsistencies.
As described in more detail in the next section, many vertical shifts and artificial datums are used when processing seismic and VSP data. If the data is not put back in the right place, a residual (and often difficult to identify) shift is embedded in the data. Seismic reference datum Initial seismic acquisition and processing occur in the time domain, along with many post-processing analytical activities such as waveletbased inversion. A convention in the seismic industry is that processed seismic records begin at a time of 0.0 sec. This 0.0 time reference point must be associated with an elevation reference point, which is known as the Seismic Reference Datum (SRD).
In almost all marine and many land cases, SRD is set at a constant value - a flat surface. However, there are cases where SRD is a non-flat surface with different values at each seismic trace. For this case, you can define the depth at which the checkshot passes through time zero. This option is available when you clear the check box Use SRD.
380 •Sonic calibration
Petrel Geophysics
>
I Marine seismic In the marine seismic case, 0.0 time typically is adjusted to mean sea level (MSL) and SRD most often is set at 0.0 feet/meters above MSL. During processing, however, data often is realigned (static shifts are applied) to alternative datums, such as water bottom or gun depth.
Q. 3
If marine data appears to be 25 feet shallower than expected, ask the processors if they remembered to move back to MSL after processing at gun depth. If they did not, the data can be zero datumed at 25 feet below MSL. Similarly, data acquired in land-marine transition areas or very shallow water can be processed using datums related to tidal fluctuations during acquisition.
There are three common datum-related causes of alignment ambiguity between seismic and well data for marine cases: • Use of a constant (or linear trend) water column velocity. (This velocity is not valid in deepwater Gulf of Mexico, proximal offshore Brazil, and other areas where salinity changes affect water column velocity.) • Inconsistencies between log and seismic shallow velocity profiles. Often, no logs are available for a significant distance below the mudline. Linear trends frequently are substituted and often are incorrect and typically too fast. • Assumption that water velocity represents the lowest possible velocity. For example, the presence of biogenic gas in near¬ shore shallow deltaic or marsh sediments can result in velocities that are significantly lower than water velocity.
Petrel Geophysics
Sonic calibration •381
I On the Datuming tab (Figure 8), the graphic display changes according to the parameters. By default, the Seismic well tie process picks up the project datum, but you can change the parameters on this tab.
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V,,.* 1480 m1% Mb * 2000 mJs
a Output fcm«(TWT)(c):
Q.
OOO ft
O UMSRD
000 ft
ElheSRO
11800 ft
3
7 -CtlKttHOt
a
a
ii
V, =2100 m/s
-a
1000m
V2= 2200 ml%
p
V-CMOM
-
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7 -ClwtaM
Figure 8 Marine datum and its parameters selection in the Seismic well tie process dialog box
Land seismic (and VSPs) The land seismic case can be more complex because of surface topography and near-surface phenomena that are not present in the marine case. It also can be more severe in the land case.
In many areas, the irregular thickness and rapid lateral variation of near-surface layers, water table anomalies, and karsting cause velocity anomalies that cannot be characterized adequately in the seismic velocity model. As a result, time shifts (static shifts) often are present from one trace to the next, causing timing perturbations that affect deep reflectors. It is common practice to try to align the traces by making minor up/down shifts so that a reflector that appears continuous and smooth takes on this appearance. This situation shifts some traces in a way that moves them above the 0.0 time point into negative time.
Similarly, larger shifts occur when data is shot beneath a water body (lake, river) or other feature with velocities that depart significantly from the seismic velocity model.
Some geophysicists (and some software systems) do not like the idea 382 •Sonic calibration
Petrel Geophysics
I <
Q. 3
of negative time. The solution is to move SRD far above the point that any trace is reasonably expected to be shifted. Often, this solution puts SRD somewhere up in the sky, especially in mountainous areas where surveys are shot over large changes in elevation.
>
In West Texas, SRD often is set at 3,000 ft MSL, although ground level often is closer to 2,300 ft MSL.
In this case, the thickness of the air gap between the SRD and the ground surface is used to compute a replacement velocity so that the first live sample on the seismic trace is located at the surface. Any subsequent static shifts are small enough that data remains in positive time. A similar situation occurs with what is known as the weathering layer. This layer is the region between the ground surface and the portion of the seismic that the geophysicist can understand. The time thickness of weathering layer velocity anomalies is estimated and weathering statics are applied that compensate for the associated timing shifts. These weathering static shifts must be taken into account when trying to align land seismic data with VSP traces that typically DO NOT have weathering statics applied. In most cases, land VSP and checkshot data are datumed (0.0 time set) at the ground surface. In areas with elevations relatively close to sea level, the data can be datumed beneath the ground surface at MSL. With third-party contractor data libraries, checkshot data is datumed at some arbitrary subsurface elevation. For example, in West Texas, this elevation is 1,000 ft MSL.
This means that 0.0 time for VSPs and checkshots often are at a different elevation than 0.0 time for the seismic data. In cases where this datum elevation is below ground level, a VSP/checkshot replacement velocity often is computed and applied so that 0.0 time is shifted to ground elevation even though the data remains positioned correctly in the subsurface. Figure 9 shows Land datum and its parameters selection in the Seismic well tie dialog box.
Petrel Geophysics
Sonic calibration •383
a
•
Land datum Marine datum Chackshot Otcund
<
KB ■ 20m above ground
Ground!
r Time datum ISRM
Vr
Weathering layer
■ 1000m
Vw = 1800 fTl/S
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000 ft
□ Ute SRD
Output tona (TWT) (c):
0 00 ft
□UaoSRD
Aboveground surface
Elevation of sonic log (a):
11800 ft
Replacement velocity (Vr)
1115 00 ft/s
Elevation of ground surface (d)
3280 00 ft
Velocity (Vw)
5905 00 ft/s
Below Weathering layer
a
a
Below weathering Elevation at the base of the weathering (e)
1312 00 <1
Velocity (Vb)
5890 00 ft/s
-3RD «-400m
a
a
[•1
m 0
Va = 340 fTl/S A
,100 depth datum (KBI
depth i
Sietsce
Above surface replacement
,
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I 1
Vw = 2100 ITl/S
-Choctohot -200m
v -CftKttfiet
M3L ■ Om
Vi = 2300 m/s V -Chackabot
900m
V, = 2500 m/s V -Choetahot
Figure 9 Land datum and its parameters selection in the Seismic well tie process dialog box
384 •Sonic calibration
Petrel Geophysics
B Seabed : Water velocity With the seabed and the water velocity options (Figure 10), you can include a new data point (time-depth pair) into the checkshot survey. :
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r
Water layer Elevation o? water surface (d) Velocity (Vw)
0 00 II 4862 20 ft's
Bekr* seabed
Depth of seabed (from MSL) (e):
Velocity (Vb)
60000 II 486220 Its
Figure 10 Seabed not taken into account (left) and seabed taken into account (right)
Petrel Geophysics
Sonic calibration •385
Time-depth tab The Time-depth tab tab (Figure 1 1 ) is divided into three main sections: • Checkshots and interpolation above TOL • Top of log time • Below of log time. This tab works with the Datuming tab to control how checkshots are used above the top of the log (TOL). It allows you to control how time values are derived and which interpolation method is used.
<
[•]
Input
Output
Datuming Time-depth
I Options |
Statistics
Track manager
All depths in this tab are measured from KB in TVD
0
a
Checkshots and interpolation above TOL Checkshots threshold depth
Just above shallowest checkshot
Interpolation type (time)
Linear
Velocity to use at start of interpolation:
Calculate automatically
Interpolation velocity at top of log.
Calculate automatically
;
■
a
Top of log time
© TVTc
■
0 at the first checkshot sample after the top of the sonic log (TOL)
o Interpolate between the two closest checkshot samples at TOL for Tl-Tc = 0
© Two-way time at the top of sonic log:
122349
a
Below of log time Maximum TVD of output time/depth
0 00] +1500ft
Below sonic replacement velocity:
0 00
m Default
Figure 1 1 The Time-depth tab in the Seismic well tie dialog box
386 •Sonic calibration
Petrel Geophysics
>
I Checkshots and interpolation above TOL This section gives you control when working with checkshots above the top of the log, that is, above the first measured sample of the log. <
These options establish how far above the top of the log (first sample of the log) the checkshots are used to define the shallow interval velocity trend.
>
Checkshots threshold depth This field can be set to one of several predefined values or entered manually if you select User from the list. This field controls the boundary between the values calculated on the Datuming tab and the values calculated from the checkshots.
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Above this depth, the output time-depth is calculated from the Datuming tab. Between the Checkshot threshold depth and the Top of sonic log (TOL), the checkshots are used. Depending on the value selected, the settings on the Datuming tab are not used.
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You can select one of these predefined values for the Checkshots threshold depth field: • Only use checkshots: The interval velocity trend comes entirely from the checkshot. above shallowest checkshot: The interval velocity trend Just • comes from the Datuming tab down to a point just above the shallowest checkshot point. From that point downward until the top of the sonic log, checkshot velocities are used. • Up to sea surface (for marine)/Up to ground surface (for Land): The interval velocity trend comes from checkshots up to sea surface in the marine case, then the values specified on the Datuming tab are used. Up • to sea bed (for marine)/Up to base of weathering (for Land): The interval velocity trend comes from checkshots up to sea bed in marine case, then the values specified on the Datuming tab are used. • Do not use checkshots above TOL: The interval velocity values specified on the Datuming tab are used regardless of the checkshots. • User: User-defined threshold depth value to start using the values specified on the Datuming tab. Petrel Geophysics
Sonic calibration •387
I Interpolation type (time) The interpolation type between the lowest datum layer and the first checkshot sample or top of log can be set to Linear, Quadratic, or Cubic spline.
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The fields Velocity to use at start of interpolation and Interpolation velocity at top of log are available only for the Cubic Spline method. For these fields, you can select Use datuming velocity or Calculate automatically. Q. 3
Top of Log time This section controls how the time for the top of the sonic log is calculated. It has these options: • Tl-Tc = 0 at the first checkshot after the top of the sonic log (TOL): This calculation is the time of the first checkshot sample below the TOL minus the time integrated up the sonic log from this depth to the top of the log. • Interpolate between the two closest checkshots at TOL for Ti-Tc = 0: The time at the top of the sonic log is calculated by interpolating linearly the two closest checkshot samples to get the corresponding sample at the same depth at the top of sonic log. • Two-way time at the top of sonic log: When checkshots are not available, this field can be used to set the two-way time to the top of the sonic log. The time is measured from the Output TWT Datum. You can use this option when checkshots are available to set this time manually.
388 •Sonic calibration
Petrel Geophysics
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I Below of Log time
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This section controls how the time/depth curve is calculated below the bottom of the log. It has these options: • Maximum TVD of output time/depth: The maximum TVD to use for the output time-depth. The time-depth is extrapolated using the Below sonic replacement velocity. +0: • Use the maximum depth of the sonic log or time-depth. • +500 m (+1500 ft): Add 500 m (1500 ft) to the maximum depth of the sonic log or time-depth. +1 • 000 m (+3000 ft): Add 1000 m (3000 ft) to the maximum depth of the sonic log or time-depth. • User: Enter a maximum depth. • Below sonic replacement velocity: The velocity to use when extrapolating the output time-depth below the sonic log. You also can select the option Default (by default, set the replacement velocity to the velocity at the bottom of the sonic log). In Figure 12, Figure 13, and Figure 14, you can see the effect of the various interpolation options above TOL. D;ar-ond-14
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Sonic calibration •389
In Figure 13, the Quadratic interpolation method is used above TOL (time of first log datum). For this dataset, the Quadratic interpolation method is not flexible. Diamond-14 [SSTVD]
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390 •Sonic calibration
Petrel Geophysics
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Petrel Geophysics
Sonic calibration •391
I Options tab The Options tab (Figure 1 5) allows you to define how knee points and residual drift curves are interpolated. <
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The tab has these fields. Knees Set the type of function that is used to interpolate the knee points. The interpolation function can be set to Linear or Cubic. The Polynomial fit function is recommended when the checkshots are used to calibrate sonic that is noisy.
This correction smooths the differences between checkshot (time-depth) pairs and the integrated sonic log, estimating a polynomial drift curve to honor the knee points without fitting the noise. Residual Set the type of function that is used to interpolate the residual drift. The interpolation function can be set to drift Linear or Cubic. Refer to Figure 16, Figure 17, and Figure 18 for examples of the various interpolation options.
392 •Sonic calibration
Petrel Geophysics
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394 •Sonic calibration
Petrel Geophysics
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Sonic calibration study template After defining the inputs and datums correctly, click Apply in the Seismic well tie dialog box. Automatically, some output data is created virtually (but it is not stored yet in the Input pane). Also, a Well Section window opens with a default template, showing the tracks described in Figure 21.
Petrel Geophysics
Sonic calibration •395
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396 •Sonic calibration
Checkshot Initial knee point (Blue) Drift (Red) Residual drift Original Sonic (Red) / Calibrated Sonic (Blue) Output interval velocity (RED)/ Input interval velocity (Blue) Two way time of TDR used as input Interval velocity of the TDR used as input Average velocity of the TDR used as input
Petrel Geophysics
I Checkshot, drift, and knees
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By default, this track contains checkshots and a proposed drift curve. The red line is made as a 2-point straight line from the start to the end of the well data.
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To edit the drift curve, you can insert knee points interactively.
Q. 3
The drift curve is derived by integrating time values from the calibrated sonic log. In other words, the drift curve times quantify how much the sonic log is corrected. The drift curve is used to adjust the overall time-depth relationship of the sonic log to the checkshot data, while retaining the high-frequency data from the sonic log data. Because the drift curve represents a relationship between the checkshot values and the sonic log, any edits to the checkshot also update the drift curve.
The reverse, however, is not true. If you edit or change the drift curve, the checkshot is not updated or changed. The horizontal axis is the difference between Tc (Time from Checkshot) and Tl (Time from sonic log integration). Residual drift The difference in time between the checkshot and drift curve is the residual drift (curve). The closer it is to zero, the more accurately the sonic matches the checkshot.
If the residual drift curve does not deviate from the zero line, it means that the log times are fully consistent with the checkshot times and the drift curve coincides with the checkshot points. Two-way time and input velocities
This data is derived from the input checkshots.
Knee points The Petrel Sonic Calibration workflow includes the ability to edit a knee curve interactively based on checkshots. The knees can be added at specific locations (using well tops, for example). You can view the calibrated sonic log while editing the knees. It also is possible to redefine the datum in the process and specify the outputs after calibration. Petrel Geophysics
Sonic calibration •397
Procedure — Use the Seismic well tie Tool Palette 1 . On the Seismic interpretation tab, in the Seismic-well calibration group, click Well tie editing to launch the Seismic well tie Tool Palette.
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398 •Sonic calibration
X-section editing
Petrel Geophysics
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I This figure shows the tools that you can use to edit knees.
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3. Edit the drift curve by interactively inserting, moving, or deleting knee points. Click Edit mode in the Seismic well tie Tool Palette and use the left mouse button to edit the drift curve. You can create knee points at checkshots or at well tops (markers). In the figure, the positions of the well tops have been used to create knee points.
Petrel Geophysics
Sonic calibration •399
Before you can use well tops, they must be displayed in the Well section window.
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I Customize the template display settings The display settings (Figure 22) can be changed in the well section template Settings dialog box for all data: sonic, calibrated sonic, residual drift points and curve, checkshots, knee points, and the drift curve. Settings for '(Study 1) Diamond-14 Sonic calibration'
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You can change the minimum and maximum values, the colors and sizes of the curves/points, and the type of line (dashed, solid). It also is possible to use additional logs or modify the order of tracks. The Well section window template settings (Figure 22) control the order of tracks. The overall display, with auxiliary logs, can provide the interpreter with many pieces of additional information. In addition to the residual drift, you can identify lithologic changes from the gamma log, washout from the caliper, and velocity abnormalities from the interval velocity log. Petrel Geophysics
Sonic calibration •401
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402 •Sonic calibration
Petrel Geophysics
I Lesson 2 — Sonic calibration through the Global well logs folder <
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The approach available in the sonic calibration workflow of Seismic well tie allows you to work with only one well at the time. You can use the method described here to calibrate multiple wells simultaneously.
Procedure — Calibrate multiple sonic logs under Global well logs 1. Right-click the Global well logs folder in the Wells folder and select Create corrected sonic log. 2. Click on the Settings tab and select the uncorrected sonic log from the list. 3. Insert the required checkshot data. 4. Define the correction curve using Least squares polynomial (orange curve in Figure 24) or Cubic spline (blue curve in
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Petrel Geophysics
Sonic calibration •403
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404 •Sonic calibration
Petrel Geophysics
I Well calibration
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The sonic calibration aligns the derived sonic times to the time values from the checkshot data. This alignment removes drift in the sonic log by adjusting the correction curve to the data points. The Least square polynomial correction curve option fits a smooth curve to the data without matching the points exactly, which results in a residual error.
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Petrel Geophysics
Sonic calibration •405
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Procedure — Quality check the Sonic log calibration The correction curve used to fit the drift points can be modified for individual wells. Often, some wells require a different fitting algorithm to approximate the drift points properly. 1. In the Input pane, navigate to the Well logs folder of an individual well and open the Settings dialog box for the Corrected sonic log. 2. Open the Settings tab. 3. Select the Override global settings check box. 4. Select a polynomial function of a different order or a cubic spline function. 5. Check the result in the Well section window.
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I In this figure, the drift curve (black) and the fit curve (red) are shown together in the fit curves track with the calibrated sonic log (second track). •14 ÍSSTVD]
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Exercises — Sonic log calibration Generally, sonic logs are preferred for building velocity models because, unlike checkshot data, they are more densely sampled. However, using the original sonic logs directly delivers incorrect velocities for seismic data conversion because they typically lack data in the upper part of the well.
Sonic logs are measured in a different frequency range than the seismic data (dispersion). They can contain cycle skipping or extreme spikes that accumulate as incorrect integrated time values through the well length. As a result, they must be calibrated with checkshots before velocity modeling.
406 * Petrel Geophysics
Sonic calibration •407
1 0
Exercise 1 — Calibrate a Sonic log using the Seismic well tie process and establishing a time-depth relationship Sonic logs that are calibrated with checkshots as part of the synthetic generation process give a more accurate time-depth relationship. This data can be saved and used later in the time-to-depth conversion. In this exercise, you use the Seismic well tie process to calibrate a sonic log and establish a time-depth relationship. 1. On the Seismic interpretation tab, in the Seismic-well
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In the Seismic well tie dialog box, click Create study. In the Type of study field, choose Sonic calibration. In the Well list, select the well Diamond-14. In the Input tab, make these selections from the lists, as shown in the figure: • Sonic Despiked for Sonic log • Diamond-14/Diamond_14.cs for TDR.
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1 6. On the Output tab, observe the different output options. Select Auto save to save all changes in the Input pane automatically and update the output in real time. If you use this option, you do not have to save the study every time you adjust the parameters. 7. For the Time-depth relationship (TDR), select the Auto save check box and click Set as active TDR.
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Sonic calibration •409
8. On the Datuming tab, the entries are filled in automatically from the project and well settings. Using the Seismic reference datum (SRD), the Seismic well tie process in Petrel automatically assumes offshore data for SRD=0 (Marine) and onshore data for other SRD values (Land). Datuming is key here. All settings are correct. Do not change the parameter values; keep the default parameters as they are for now.
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Open the Time/depth tab. On this tab, you control how checkshots are interpolated above the Top of the log (TOL). These options define how far above the top of the log (first sample of the log) the checkshots are used to define the shallow interval velocity trend. It is possible to extend the time-depth output below the log by using a sonic replacement velocity. For this exercise, use the default parameters.
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Sonic calibration »411
1 0. On the Options tab, keep the Knees and Residual drift fields set to Linear. Iÿl
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11. Click Apply to create the Sonic calibration study. A new Well section window opens with a default template.
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This curve is updated based on the knee manipulations on the Drift and Knees track.
Petrel Geophysics
Sonic calibration •413
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The last curve is updated based on the knee manipulations on the Drift and Knees track. Output and Input interval velocity: Shows both interval velocities (input and output) in the same track for quality control purposes. Interval velocity: Shows the interval velocity of the TDR used as input (checkshots). Average velocity: Shows the average velocity of the TDR used as input (checkshots). TWT picked: Shows two-way time of the TDR used as input (checkshots).
12. On Seismic interpretation tab, in the Seismic-well calibration group, click Well tie editing to open the Tool Palette. Home
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Petrel Geophysics
I 18. Observe that the original and the calibrated sonic log curves are different. When you move a knee point, the curves are updated, as shown in the figure (third track, red, and blue curves). The result of the calibration creates a new more accurate time-depth relationship for the well.
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19. Open the Output tab of the Seismic well tie dialog box. 20. Rename Calibrated sonic log as Calibrated sonic_l and click Save. ill Seismic well tie
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21. For the Time-depth relationship (TDR) field, make sure that the Auto save option is selected and click on Set as active TDR button.
Petrel Geophysics
Sonic calibration •417
I This time-depth relationship is used for the time conversion of the well Diamond_14. The relationship is selected automatically on the Time tab of the Settings dialog box for Diamond_14. These options override the options in the Global settings dialog box. T
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22. Adjust the knees if necessary and observe the effect on the Interval velocity output. Verify that you are satisfied with its shape. 23. On the Home tab, in the Transfer group, click Reference project tool to open Reference project tool dialog box. 418 «Sonic calibration
Petrel Geophysics
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24. Find Cloudspin_SecondaryProject.petFT\n the Secondary projects folder and open it. (If the Petrel message log appears, view the content and close it.) All available data in the selected reference project is listed on the right side of the Reference project tool dialog box. 25. Select the check box for the Wavelets folder and use the blue left arrow to copy this folder from background project into your working project. You will use this folder in later modules. 26. Save your project.
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Petrel Geophysics
Sonic calibration •419
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Review questions • Why do you calibrate a sonic log with the checkshot data? • What would you do if checkshot data is not available for a well?
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Summary In this module, you learned about: • calibrating a sonic log • selecting input data and parameters • defining knee points and outputs
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Petrel Geophysics
I Module 8 — Synthetic seismogram generation
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In this module, you learn about synthetic generation, reflection coefficient calculation, interactive bulk shift or continuous alignments, and the correlation tool and track.
Learning objectives After completing this module, you will know how to: • use the synthetic generation process and input data • calculate the reflectivity coefficient • Use of interactive bulk shift or continuous alignments to adjust the time shifts between synthetic and seismic • use correlation tools and track • model the reflection coefficient (RC) • quality check Interval velocity
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Lesson 1 — Synthetic seismogram generation workflow Synthetic seismograms are the bridges between geological information (well data in depth) and geophysical information (seismic in time). Synthetic generation involves these steps: 1. Time convert the wells with checkshot data or a sonic log to establish a time-depth relationship. 2. Calculate acoustic impedance and reflection coefficients from different logs (usually density and sonic logs). 3. Generate or extract a wavelet. 4. Generate synthetic seismograms from density logs, sonic logs, and a seismic wavelet by calculating acoustic impedance and reflection coefficients. These calculations then are convolved using a wavelet. The Synthetic generation workflow used in the Seismic well tie process includes the ability to tie a synthetic seismic trace with seismic data.
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Procedure — Generate a synthetic seismogram 1. On the Seismic interpretation tab, in the Seismic-well calibration group, click Seismic well tie. Petroleum Systems
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2. Create a new study. 3. Select Synthetic generation as the Type of study. 4. Select the well.
422 •Synthetic seismogram generation
Petrel Geophysics
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Synthetic seismogram generation •423
I 9. Choose a Reflectivity coefficient calculation method and associated input data.
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10. Click Apply in the Seismic well tie dialog box. A Well section window opens, showing the output result. Q.
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The red line on the Seismic track represents the Well trajectory. The display is controlled in the Well section template Settings dialog box. Additional seismic tracks in the Well section window can be added where attributes can be displayed. Well trajectory, logs, and synthetic seismograms can be displayed. 424 •Synthetic seismogram generation
Petrel Geophysics
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Synthetic track: Synthetic seismogram created convolving the reflectivity series and the wavelet. If any of the input data is modified, this track is updated instantly. Correlation track: A tool that helps increase the confidence in matching synthetic seismogram to seismic data. Each trace in the Correlation track represents the degree of correlation between the synthetic and each of the traces contained in the Seismic track as the synthetic is shifted vertically relative to the seismic.
The information from this correlation track is used to determine the correct time shift to be applied to the synthetic or seismic with the goal of achieving an optimal match. Interval Velocity track: The output interval velocity and also the place where the Interval velocity manipulations take place. Input/Output Interval Velocity track: The input and output interval velocities in the same track for quality control.
The input interval velocity is active in the well (from the active TDR); the output interval velocity is the result after the time shifts (bulk and stretch/squeeze) are applied in the synthetic. The default template for the synthetic generation study presents simultaneous display of the time and depth index tracks in Well section window. 9 Drift track: The time shift (in ms) applied in the synthetic to tie with the seismic. This shift comes from the bulk and stretch/ squeeze. 10 Well trajectory
Petrel Geophysics
Synthetic seismogram generation •425
I Seismic well tie dialog box tabs In this section, you get a more detailed look on the options available on the different tabs of Seismic well tie dialog box. >
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Input tab The Input tab (Figure 1 ) in the Synthetic generation study is used to control the input of logs, time/depth relationship, wavelet, and reference seismic to generate synthetic trace.
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The Seismic to well tie process needs to be, in many cases, very interactive, and different kinds of TDRs must be selected as input in the study. In Petrel 2015.1, any TDR, sonic log, or velocity log contained by the well can be selected as TDR input for the synthetics generation study. For those cases where the sonic log or velocity log are selected, the synthetics seismogram will be posted from 0 TWT. Therefore, it will be out of place and the Bulk shift is a required step in the Seismic to well tie process.
426 •Synthetic seismogram generation
Petrel Geophysics
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Petrel Geophysics
Synthetic seismogram generation •427
Wavelet
In the Wavelet box, insert the wavelet to be convolved with the reflectivity series to create a synthetic seismogram. If no wavelet is available in the project, open the wavelet toolbox to create a new one by clicking Launch wavelet toolbox
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Seismic display In the Seismic display section, you drop in the seismic that is used as a reference to compare the seismic-synthetic tie. Both 2D and 3D seismic surveys are allowed, so you can use a 3D cube or a 2D line.
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There are three seismic display positioning methodologies for the Seismic well tie process: Well head location, Deviated well location, and Selected Wavelet: Q.
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Petrel Geophysics
Synthetic seismogram generation •429
I Deviated well location This method sets the inline-crossline to the location of the well track at the center of the analysis window, as shown in Figure 4. The figure shows how the deviated well is displayed in the seismic track. This method considers the entire trajectory as the display position window, calculating the position point (XY location) as the center of the extraction window.
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The Xline window represents the number of crosslines to be used for seismic reference on either side of the well location. These crosslines are counted from the crossline position that you define.
For example, if you enter 4 in the Xline window, five crosslines are displayed: one that corresponds to the crossline 570 (well position) and four other crosslines after your reference, which is the number that you entered.
430 •Synthetic seismogram generation
Petrel Geophysics
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Selected wavelet This method sets the Inline-xline to the location of the currently selected wavelet, as shown in Figure 5. The figure shows how the well is displayed in the seismic track according to the position obtained through the wavelet selected on the Predictability map.
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Petrel Geophysics
Synthetic seismogram generation •431
Reflectivity coefficient calculation There are several methods for generating reflectivity coefficients, depending on the availability of data (Figure 6): • Acoustic Impedance • Sonic and Density logs • Shear • Porosity • Aki and Richard PP • Aki and Richard PS • Any log
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Figure 6 Reflectivity coefficient options in the Seismic well tie dialog box 432 •Synthetic seismogram generation
Petrel Geophysics
I Here are some examples of how to calculate the reflectivity coefficient using different types of data:
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Choose an Acoustic Impedance. It this case, a sonic and density need not be present. The Seismic well tie process calculates a reflection coefficient curve.
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Use any log curve as a pseudo-Acoustic Impedance curve for apparent reflectivity computation. Gamma logs often work well in this circumstance. Sonic logs also work well, but the polarity typically is reversed from the log derived from true acoustic impedance.
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Use sonic and density curves to generate the Al curve as the ratio between the density and the sonic logs. In turn, the RC curve is generated from the Al curve. The Seismic well tie process generates this curve on-the-fly.
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The original sonic log (or a despiked version of the original input sonic) is used in this calculation. The calibrated sonic log is likely to contain abrupt shifts (at knee point positions) as a result of this calibration. Using the calibrated sonic as input to this process results in the same abrupt shifts in the acoustic impedance log. Because the reflection coefficients are calculated from the acoustic impedance log, the result again introduces reflection coefficients and artificial events in the synthetic trace.
Gardner's patching: Auto-complete reflection coefficient inputs Petrel can automatically complete missing sections of Density or Sonic logs using Gardner's equation. This option fills the gaps where one of the input logs (Sonic or density) is missing. For examples, refer to Figure 7 and Figure 8. One of the logs must exist to compute the other one:
P = aZnpb In this equation, • a = The Constant unit (imperial/metric). It is shown next to the Constant box. For the Exponent parameter, the default value is 0.25. You can change values for these two fields and them as parameters for Gardner's equation. b • = Exponent. If the project is in the Imperial system, the default value is 0.23 for the Constant parameter. If the project is in the metric system, it converts the default imperial value to metric using this equation: a (in metric) = a (in imperial) * (1000/(0.3048 A exponent )) Petrel Geophysics
Synthetic seismogram generation •433
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Synthetic seismogram generation •435
Output tab Use the Output tab (Figure 9) in the Synthetic generation study to control the output results from the workflow. You can change the name of any output and save it in the Input pane by clicking Save r J. IÿI
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Figure 9 Output tab in the Seismic well tie dialog box 436 •Synthetic seismogram generation
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These output types are available from Output tab. All output is saved in the Input pane: • Seismogram: Saved as a seismic log in the Global well logs folder and the well used in the study. • Reflectivity: Saved in the Global well logs folder and the well used in the study. • Computed seismogram (depth)/ Synthetic in depth: The synthetics used to be a time domain object. In Petrel 2015.1, the synthetics that is generated can be saved with depth as the vertical index.
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You can automatically save all of the outputs, so that after they are saved the first time, any manipulation overwrites the output. If the name of the output is already in the Input pane, a pop-up warning asks you to confirm your decision to overwrite it.
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Computed acoustic impedance: Saved in the Global well logs folder and the well used in the study. Resampled acoustic impedance: Saved in the Global well logs folder and the well used in the study. Partial seismogram from RC modeling: Saved in the Global well logs folder and the well used in the study. Seismic trace used in the single trace correlation: The average or composite seismic trace extracted based on a radius that you define. This option is available only if you choose the option Single trace on the Correlation tab. The seismic trace is saved as a seismic log in the Global well logs folder and the well used in the study.
Petrel Geophysics
Synthetic seismogram generation •437
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I Synthetic generation template After all of the input data/parameters are selected in the Seismic well tie dialog box and the synthetic is generated, the template shown in Figure 10 opens. It displays the different input data and resultant synthetic seismogram.
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Input logs track: Logs used for the Reflectivity series calculation. Reflectivity track: Reflectivity series calculated based on the method selected on the Input tab. Wavelet track: Wavelet, power spectrum, and phase spectrum of the wavelet used for the synthetic generated.
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Seismic track: Seismic section used as a reference to compare the seismic-synthetic track. The extension/orientation of this section is controlled from the Input tab.
The red line on the Seismic track represents the Well trajectory. The display is controlled in the Well section template Settings dialog box.
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Additional seismic tracks in the Well section window can be added where attributes can be displayed. Well trajectory, logs, and synthetic seismogram can be displayed. Synthetic track: Synthetic seismogram created by convolving the reflectivity series and the wavelet. If any of the input data is modified, this track is updated instantly. Correlation track: A tool that helps increase the confidence in matching the synthetic seismogram to seismic data. Each trace in the Correlation track represents the degree of correlation between the synthetic and each of the traces contained in the Seismic track as the synthetic is shifted vertically relative to the seismic. The information from this correlation track is used to determine the correct time shift to be applied to the synthetic or seismic with the goal of achieving an optimal match. Interval velocity track: The output interval velocity. Also the place where the Interval velocity manipulations take place. Input/Output interval velocity track: The input and output interval velocities in the same track for a quality control. The input interval velocity is active in the well (from the active TDR). The output interval velocity is the result after the time shifts (bulk and stretch/squeeze) are applied in the synthetic.
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Simultaneous display of the time and depth tracks: The default template for the synthetic generation study shows simultaneous display of the time and depth index tracks in Well section window. Drift track: The time shift (in ms) applied in the synthetic to tie with the seismic. This shift comes from the bulk and stretch/
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Synthetic seismogram generation •439
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Synthetic seismogram generation •441
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Synthetic seismogram generation •443
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I Interpretation display on seismic track There are many references to be used as a guide during the seismic to well tie process. Usually, the main reference will be markers and horizons; while, in some other cases, it could be faults or other types of identified interfaces. In Petrel 2015.1, horizon interpretations and fault interpretations can be posted in the seismic track, which helps to use them as reference during the tie process.
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Select this seismic object on the Interpretation tab, which contains the tools to add the interpretation (horizons and faults) in the track.
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Synthetic seismogram generation •449
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I 7. Seismic cube display and style settings can be changed. 8. Click Apply. •
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I Correlation track The Correlation tool provides information for a better seismic synthetic match. This tool calculates the cross-correlation between synthetic and seismic, which is achieved by calculating the time shift to be applied to the synthetic.
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Although the correlation display looks like seismic data and uses similar display mechanisms, it is NOT seismic. Do not look for correlations between this display and the seismic track. Each trace in the Correlation track represents the degree of correlation between the synthetic and seismic, because the synthetic is shifted vertically relative to the seismic.
Q. 3
This calculation is repeated every time, according to the seismic sample rate, and for every seismic trace. Remember that each value represents how well the synthetic matches the seismic trace at a particular point in time over the entire interval that you specified. The result of these calculations is a series of numbers for each seismic trace.
These values are normalized to ±1 and displayed as curves in the Correlation track. These values correspond to the same positions as the seismic traces. When you place the cursor over the Correlation track, you can read the Inline and Xline positions, the correlation value corresponding with the mouse position (Current position), and the Max correlation from the box labeled in the upper right side of the track (see Figure 11 and Figure 12). Irlme 622 & X -e 565 Current posean (-0 116. -30Sms. Odeg) Max correlator (0.504 -Sms. Odeg) Max after rotate (O 4S6 Oms 63deg) Max after rotate and shift (0.513, -4ms. 26degj
Figure 11 A box in the upper right side of correlation track showing correlation values, lag value, and phase rotation
Inside the parenthesis, these values are displayed: • Correlation value • Time value that corresponds to the suggested time to shift (lag value)
• 452 •Synthetic seismogram generation
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Petrel Geophysics
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If the Compute phase mistie option (Figure 1 5) is active on the Correlation tab, a new line of information (number 4) is displayed. This information shows the phase rotation to be applied to the wavelet to improve the tie. The time lag for this option is zero, meaning the synthetic was not shifted.
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If the phase mistie option is active on the Correlation tab, a new line of information (number 5) is displayed. This information shows the phase rotation to be applied to the wavelet to improve the tie. Q. 3
You can see that the time lag for this option is different from zero, meaning that the synthetic was shifted. With this result, the interpreter knows what time shift or what phase applies to get the best correlation. Mint 622
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Synthetic seismogram generation •453
I Correlation lag The lag value at any point in the Correlation track is the time shift applied to the synthetic to move it into the position where it was when the correlation values were calculated.
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For example, the correlation values at a lag of 0.2 seconds are the result of the correlation calculation made when the synthetic is shifted down 0.2 sec (or 200 ms). The correlation values at lag zero represent the synthetic/seismic relationship as it appears currently. The correlation values reflect a current correlation is not high. In this case, the visual match between the synthetic and seismic is not good.
Q. 3
The largest correlation value on each trace is marked with a symbol. A red diamond marks the trace posted on the Correlation track with the point of highest correlation (Figure 13). This symbol represents the best mathematical match found between synthetic and seismic (in the Time lag window). The lag value at this symbol is the amount of bulk shift that you would need to apply to move the synthetic into this best match position.
An asterisk marks the optimum point of correlation for the entire series of traces used in the correlation generation operation. This symbol is the global optimum correlation value of the best match among all of the traces.
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454 •Synthetic seismogram generation
Petrel Geophysics
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I The Time lag window is defined on the Correlation tab in the Window section of the Seismic well tie dialog box (Figure 14). The Correlation tab in a Synthetic generation study is used to define the Time lag window for the Correlation track. For example, if you define a Start time of 1800 ms and an End time of 2200 ms, the time lag window is 400 ms. The Correlation track displays 200 ms below and 200 ms above. ■J! Seismic wefl tie
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Petrel Geophysics
Synthetic seismogram generation •455
Correlation tab This tab controls the display parameters of the Correlation track. It is divided into these three main sections (Figure 1 5): • Window • Trace • Phase mistie
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Figure 15 Three main sections of Correlation tab 456 •Synthetic seismogram generation
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I Depending on the options that you select, the correlation between the seismic traces and the synthetic are updated. <
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You can specify your preferences, such as Start time and End time. You also can specify visualization of the trace, or compute the phase mis-tie in the wavelet phase to improve the synthetic/seismic tie.
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Window section To specify a start time (ms) and end time (ms) for the vertical correlation interval, use the Window section on the Correlation tab. You can establish the limits of interest or choose the Automatic set limits option (default). This option takes the complete time window defined by the synthetic.
Every time that you make corrections in time, seismic, and other parameters (such as stretch and squeeze, and bulk shift), the correlation panel is updated. Trace section There are three options to select the number of traces to calculate the correlation: Match seismic traces, User defined, or Single trace.
Petrel Geophysics
Synthetic seismogram generation •457
I Match seismic traces option By selecting this option, you can visualize the generated correlation traces using the entire range of the reference seismic defined in the
Seismic display section of the Seismic well tie dialog box.
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For example, if the number in the Xline window field (Figure 1 6) to be used for reference seismic on either side of the well location is four, five crosslines appear in each track of the seismic: one that corresponds to the Xline 381 (well position in this example) and four other crosslines after your reference (the number that you entered).
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458 •Synthetic seismogram generation
Petrel Geophysics
I However, the Xline 381 that corresponds to the well location is
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This means that the correlation track displays nine correlation traces, which correspond to eight seismic traces plus the one that is related to the well position. Each trace displayed in the correlation track is a cross-correlation between the trace in the seismic track and the synthetic.
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User defined By selecting this option, you specify the range of traces to be used to generate the correlation (Figure 17).
If Start trace is 0, the first seismic trace to be used in the cross¬ correlation is the first one defined in the Seismic track. Following the previous example, this trace is 377.
Petrel Geophysics
Synthetic seismogram generation •459
I Single trace
With this option, a single trace is calculated (Figure 18) following the well trajectory. The traces used in the calculation for this single trace (average trace) are the traces contained within a radius that you determine (Figure 19). Radius=2 traces
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I Figure 20 shows Trace options on the Correlation tab in the Seismic well tie dialog box for trace-by-trace correlation and single trace (average based on a radius) correlation.
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Phase mistie The previous correlation options consider the time shifts to be applied in the synthetic to improve the synthetic/seismic tie. This functionality calculates the correlation between the synthetic/seismic while considering the phase of the wavelet. See Figure 21. A scan is performed at 360 degrees with a one-degree step. This scan generates the correlation between the synthetic and the seismic for each of the 360 samples. The output of this process is a suggested phase rotation value. You can apply this value at the active wavelet to improve the tie between seismic and the synthetic. Petrel Geophysics
Synthetic seismogram generation •461
1 Because this option is computationally costly, it is not enabled by default. ■;.|1 Seismic well tie Seismic wd tie
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Time shift: Interactive bulk shift or continuous alignment The alignment of the well data to the seismic data can be adjusted to improve the tie between the seismic and well data. It also can be used to improve the estimated wavelet. You can apply interactive bulk shift or continuous alignments as discussed in the following sections.
462 •Synthetic seismogram generation
Petrel Geophysics
I Interactive bulk shift
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After generating the first version of the synthetic seismogram using logs and a wavelet, traditionally, the next step in seismic well tie process is to perform a bulk shift in the synthetic to get a closer match between the synthetics and the seismic.
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Procedure — Use interactive bulk shift 1. On the Seismic Interpretation tab, in the Seismic-well calibration group, click Well tie editing to open the Tool Palette Seismic Interpretation
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Synthetic seismogram generation •463
I 3. Click the position where to add the alignment point (in the seismic track or the synthetic track). Because it is a bulk shift of the entire synthetic seismogram, the position of the Bulk shift line is irrelevant and is used only as a visual reference. 4. Move the line up or down to the corresponding event (in the seismic track or the synthetic track).
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Synthetic seismogram generation •465
The interactive bulk shift synchronizes with the Time shift tab in the study; any change made graphically updates the bulk shift box on the fly. 1ÿ1
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TIP: Best practice is to perform the bulk shift before the stretch and squeeze. Any change in the bulk shift is added to the alignment points but no change to the alignment will affect the bulk shift. 7. Another operation available in the Tool Palette for the bulk shift is Delete bulk shift
Petrel Geophysics
, which resets all the values.
Synthetic seismogram generation •467
I Continuous alignment In the seismic to well tie process, sometimes small adjustments have to be made to match the synthetics with the seismic after the bulk shift is implemented. To perform these adjustments, we use the alignment functionality and this process is interactive.
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1 5. In step 4, the synthetics is not yet aligned with the analogous event in the seismic. To apply the alignment, Align points
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470 •Synthetic seismogram generation
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Petrel Geophysics
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Synthetic seismogram generation •471
7. The values of the alignments are reported through the alignment line. You also can modify the format of the alignment line on the Style tab of the study. ¿11 Seismic well tie Seismic wel be
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472 •Synthetic seismogram generation
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Petrel Geophysics
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Quality check interval velocity The Synthetic generation process has two tracks for quality checking. The first track displays the Input Interval Velocity vs. Output Interval Velocity. The second track displays the Drift curve in time for the shifts applied (Figure 22).
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When time shift is applied to tie the synthetic with the seismic, this tool gives the information about the resultant interval velocity and the time shift applied to the alignment points. These tracks act as guides for the synthetic generation process and velocity editing.
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Synthetic seismogram generation •473
I Interval velocity manipulation Editing/manipulating the interval velocity can be done on-the-fly to check the impact on your data.
You can edit the velocity values visually in a Well section window. Use the Seismic well tie Tool Palette to manipulate and delete velocity points. You also can lock the velocity manipulation into vertical and horizontal directions. Figure 23 shows the Seismic well tie Tool Palette where you can click different tools to perform these functions:
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474 •Synthetic seismogram generation
Petrel Geophysics
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I Figure 24 illustrates the Interval velocity track. In the Interval velocity profile, you can manipulate the points when the Edit mode and Manipulate interval velocity tools are switched on in the Seismic well tie Tool Palette. >
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The sampling of the interval velocity can be set on the Output tab of the Seismic well tie dialog box in the Time/depth relationship (TDR) section (Figure 25). Remember that the interval velocity is an attribute of the checkshot.
Petrel Geophysics
Synthetic seismogram generation •475
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476 •Synthetic seismogram generation
Petrel Geophysics
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I The interactive manipulation feature can be an important tool for quality control purposes, especially if you have information about the lithology (from the driller or geologist, for example) because you know what range of velocity to expect (Figure 26). <
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Petrel Geophysics
Synthetic seismogram generation •477
I Reflection coefficient (RC) modeling The Reflection Coefficient (RC) modeling tool is used for studying tuning effects. This tool can help you better understand the correlation between depth logs and seismic data.
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You can access this tool during the Synthetic generation process. Accessing it in this way allows you to select/clear RC areas or individual coefficients and see the results as a partial synthetic. This process helps you better understand how these coefficients can impact the synthetic response and allows you to filter problematic areas from your synthetic.
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Figure 27 shows buttons available for Reflection Coefficient (RC) modeling on the Seismic well tie Tool Palette.
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Ü Delete single RC selection Delete all RC selections By using the RC modeling process, you can select/deselect reflection coefficients and see the impact in the new synthetic created through RC modeling (Figure 28).
478 •Synthetic seismogram generation
Petrel Geophysics
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Synthetic seismogram generation •479
I The result appears in the Well section window in the tracks shown in Figure 29.
The Save options of Partial Synthetic can be accessed on the Output tab in the Seismic well tie dialog box.
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480 •Synthetic seismogram generation
RC track
Petrel Geophysics
I Procedure — Perform Reflection coefficient (RC) modeling
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in the Seismic well tie Tool 1. Click Activate RC modeling Palette. Three more tracks appear in the Synthetic display of the Well section window (WSW). The first track is the Partial Synthetic, the second track is Positive component, and the third track is Negative component.
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2. When the Activate RC modeling tool is switched on, go to your RC series track and select/clear areas of your log to see the impact on your Synthetic. Click to select the positive reflectivity. You see a component in the positive track and the resulting synthetic (that is, in the partial synthetic track). You can select multiple areas (positive reflectivity as well as negative reflectivity) in the RC series track for your synthetic.
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Petrel Geophysics
Synthetic seismogram generation •481
3. Save your partial synthetic. On the Output tab of the Seismic well tie dialog box, click Save or select the Auto save check box, as shown in the figure. ;JI Seismic well tie
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Petrel Geophysics
I Track manager The Track manager tab provides a shortcut to help you manage the tracks that you want to display within the study. <
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When you generate a study, the default tracks are checked; however, if you consider the visualization of some of them to be unnecessary and want a cleaner window, this operation can help you. Clear the tracks that should not be displayed.
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The tracks can be hidden/posted by selecting the check box. The Well section window template controls the positioning of each track.
Petrel Geophysics
Synthetic seismogram generation •483
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Lesson 2 — Integrated seismic well tie The Integrated seismic well tie study (Figure 31 ) is an integrated process in which Sonic calibration and Synthetic generation are done simultaneously using the same Well section window canvas. The sonic calibration and synthetic generation parameters are defined together to run an integrated seismic well tie study. B
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Figure 31 Integrated seismic well tie 484 •Synthetic seismogram generation
Petrel Geophysics
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I Integrated seismic well tie study template
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Both processes are fully integrated under the same canvas (Figure 32). Operations such as zoom and well top correlations are consistent across the window.
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Similar to the Sonic calibration and Synthetic generation, you can select a template for the study or use the default template. Synthetic Generatior
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Synthetic seismogram generation •485
I The default template Is an integration of the default templates used by Sonic calibration and Synthetic generation studies. The first section is related to the Sonic calibration and the second section is related to the Synthetic generation. >
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Synthetic seismogram in the Interpretation window The Seismic to well tie process is a stand-alone process; however, all outputs from the process can be integrated with other processes and displayed in different windows.
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In an Interpretation window, you can display the wellbore trajectory with the synthetic seismogram to identify the seismic reflectors that represent the geological well tops (markers) before starting horizon interpretation. Display the seismic intersection in the Interpretation window. In the Global well logs folder, choose the Synthetic seismogram.
In Figure 33, a Synthetic seismogram appears along the well trajectory to identify the seismic reflectors that represent the geological well tops (markers). Sffl-B’ T
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Synthetic seismogram in a 3D window When the time-depth relationship is established, display the inline and crossline at the well position with the synthetic seismogram in a 3D window (Figure 34) in time domain (TWT).
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Displaying this data in a 3D window provides a visual way to quality control the match between the synthetic seismogram and the real seismic data. L Q.
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Obtain a synthetic match Problems can arise when you generate a synthetic that does not match the seismic. It is important to be aware of the issues when generating a synthetic that can lead to such problems.
If seismic data was not processed to an optimum level, data had issues with energy scattering due to surface terrain, or logging shows other problems (too few runs or bad runs), the synthetic might not fit at all. Similarly, if you do not choose the correct datum or you do not edit the logs properly, the synthetic is unlikely to tie to the seismic.
Petrel Geophysics
Synthetic seismogram generation •487
I There are many reasons for a poor match: • Poorly edited log data • Poorly defined reflectivity series • Not enough/poor log data (the logging run is too short to be useful for synthetic) • Issues with data acquisition (acquisition noise, energy scattering, diffractions from fault plane, or gas effects) • Seismic data processing issues (noise, velocity, or multiples) • Not enough depth information • Poorly defined wavelet • Misleading datum information.
Q. 3
Exercises — Generate a synthetic seismogram The result of the previous exercises has produced a calibrated timedepth relationship, which is selected on the Time tab of the well Diamond-14 Settings dialog box. Exercise workflow 1. Generate a synthetic seismogram using a predefined wavelet. 2. Apply interactive bulk shift or continuous alignments to adjust the time shifts between synthetic and seismic. 3. Set synthetic seismogram display settings. 4. Display the synthetic seismogram in an Interpretation window.
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Exercise 1 - Generate a synthetic seismogram using a predefined wavelet In this exercise, you generate a synthetic seismogram using an existing wavelet. 1. On the Seismic Interpretation tab, in the Seismic well calibration group, click Seismic well tie. Petroleum Systems
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2. Create a new study and select type of study as Synthetic generation. 3. Select the well Diamond-14 from the Well list. The study name is updated, depending on the well that you select. You can change the name of the study. 4. Select Calibrated TDR in the TDR list. 5. Select Analytical Wavelet from the list next to Wavelet. This wavelet is a simple Ricker wavelet that is stored in the Wavelets folder in the Input pane. You also can create a new wavelet by clicking Wavelet toolbox ln the Seismic-well calibration group.
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6. Select mig [Realized] 1 next to the Seismic field. 7. In the Reflectivity coefficient section, choose Sonic velocity and the density calculation method. 8. In the Sonic and Density fields, select Sonic Despiked and RHOB.
Petrel Geophysics
Synthetic seismogram generation •489
9. The Seismic well tie dialog box should look similar to the figure. Click Apply to generate the synthetic seismogram. T.|I Seismic well tie
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The synthetic seismogram is generated virtually and a new Well section window opens. 10. Zoom inside the well section: a. In Select/Pick mode, place the cursor in the track (TWT), between the gray and the white area. b. Click and drag the cursor to stretch or squeeze the display. •
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1 11. In the Position section of the Input tab in the Seismic well tie dialog box, click Set display position to deviated well <
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The seismogram is stored in the Input pane in the Global wells logs folder in the (Study ...) Diamond-14 Synthetic generation folder. 13. Similarly, save the computed acoustic impedance; you will use it in the next lesson. (Study 2) Diamond-14 Synthetic generation
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492 •Synthetic seismogram generation
Petrel Geophysics
I Exercise 2 - Make interactive bulk shift and continuous alignments After generating the first version of the synthetic seismogram using <
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If the quality of the tie between the synthetic and the seismic is good enough, a stretch and squeeze will not be necessary and is not recommended as the first approach, and all updates are applied as soon as they are required. 1. On the Seismic interpretation tab, in the Seismic well calibration group, open the Well tie editing Tool Palette.
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Synthetic seismogram generation •493
I 3. Click the position where to add the alignment point (in the seismic track or the synthetic track). Because it is a bulk shift of the entire synthetic seismogram, the position of the Bulk shift line is irrelevant and is used only as a visual reference. 4. Move the line up or down to the corresponding event (in the seismic track or the synthetic track). 4- Diamond- 14 [T'.'.T
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Synthetic seismogram generation •495
7. You can modify the format of the bulk shift line from the Style tab of the SWT in the study. fill Seismic well tie <
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8. Click Delete bulk shift <1 in the Tool Palette, This resets all the values. Now you will perform continuous alignment in the following steps.
In the seismic to well tie process, sometimes small 496 •Synthetic seismogram generation
Petrel Geophysics
1 adjustments must be made to match the synthetics with the seismic after the bulk shift is implemented. To perform these adjustments, we use the alignment functionality and this process is interactive.
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I 1 0. In step 9, the synthetics is not yet aligned with the analogous event in the seismic. To apply the alignment, Align points
H in the Seismic well tie Tool Palette must be switched on and the alignment points can be edited when the Align
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points IM] is switched on. Repeat Step 9 through Step 1 0 as necessary. during a study if an 11. Use Delete alignment point alignment point needs to be deleted. If it is activated, the alignments points can be deleted by clicking over the alignment point line. In the case where the study needs to be reset, you can use
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498 •Synthetic seismogram generation
Petrel Geophysics
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12. The values of the alignments are reported through the alignment line and you also can modify the format of the alignment line from the Style tab in the study. til Seismic well tie Seismic well tie
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Petrel Geophysics
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Synthetic seismogram generation •499
I 13. On the Output tab, change the name of the Synthetic seismogram to Diamond-14_mig [Realized] l_synthetic l_shifted and click Save Í . | Input l Output
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Exercise 3 - Change the synthetic seismogram display settings 1. Open the Template settings dialog box for the Well section
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2. Experiment with the parameters and observe the changes. For example, you can clear the interpolated density and density fill check boxes for the surrounding seismic traces and the synthetic seismogram respectively (as shown in the figure). @ Sitting» for ’(Stoidy 2) Diamond-14 Synthetic generation-
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502 •Synthetic seismogram generation
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Exercise 4- Display the synthetic seismogram in other windows 1. Open a new Interpretation window and display cross line 560 from the mig Realized] 1 cube. 2. Display the well Diamond-14 in the same window with Dallas, Houston, Kobe, and Paris well tops.
Petrel Geophysics
I 3. Select the synthetic seismogram Diamond-14_mig [Realized] 1_synthetic 1_shifted in the Global well logs folder in the Input pane.
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4. With the aid of the synthetic seismogram, identify the seismic reflectors that represent the well tops.
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5. Open a 3D window and display the inline and crossline at the well position with the synthetic seismogram to quality control the match between the synthetic seismogram and the real seismic data. Make sure that the domain of the window is set toTWT.
Petrel Geophysics
Synthetic seismogram generation •503
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Review questions
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List seven ways to calculate a reflectivity coefficient in Petrel. What is meant by use of interactive bulk shift or continuous alignments to adjust the time shifts between synthetic and seismic? Why do you quality check input and output interval velocities in the Seismic well tie process? What is Reflection Coefficient (RC) modeling, partial, positive, and negative synthetics? Can you save partial synthetic seismograms? If yes, how?
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Summary
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In this module, you learned about: • using the synthetic generation process and input data • calculating the reflectivity coefficient • interactive bulk shift or continuous alignments to adjust the time shifts • using correlation tools and track • modeling the reflection coefficient (RC)
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504 •Synthetic seismogram generation
Petrel Geophysics
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I Module 9 — Wavelet generation <
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Seismic-to-well tie is key at any stage of the development of a field and is an essential step of the seismic interpretation workflow, bridging the gap between the time and depth domains. Equally, it plays a key role in the wavelet extraction process as it is involved in seismic inversion for reservoir characterization workflows. In this module, you learn different methods to generate a wavelet in Petrel.
Learning objectives After completing this module, you will know how to: • use the Wavelet toolbox • use the Analytical, Statistical, Deterministic, and Wavelet averaging methods • Multi-well extended white wavelet extraction (MWEW) • Time varying wavelet
Petrel Geophysics
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Wavelet generation •505
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Lesson 1 — Wavelet toolbox The Wavelet toolbox (Figure 1) integrates all related processes (Wavelet extraction. Wavelet Builder, and Wavelet viewer) in a single canvas. The toolbox provides an interactive tool that is easy to use.
All methods and their respective algorithms and parameters are available in the Wavelet toolbox. You also can use options in the toolbox to visualize these objects, without creating multiple windows to generate different types of wavelets.
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506 •Wavelet generation
Petrel Geophysics
Accessing the Wavelet toolbox You can open the Wavelet toolbox in one of these ways (Figure 2): On the Seismic interpretation tab, in the Seismic well <
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Click Wavelet toolbox in the Seismic well tie dialog box (2). From any wavelet in the Input pane, right-click the wavelet name and select Open in wavelet toolbox( 3).
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Figure 2 Accessing the Wavelet toolbox Petrel Geophysics
Wavelet generation •507
I Types of wavelets A simple 1D synthetic seismogram is computed by convolving a reflectivity series with a wavelet. Amplitude and phase spectra in the frequency domain define a wavelet.
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The Wavelet toolbox offers five ways to extract wavelets: • Analytical • Statistical • Deterministic • Multi wavelet average • Multi well
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Analytical method Analytical wavelets are standard model wavelets. There are five analytical wavelet types available in Petrel: Ricker, Ormsby, Tapered Sine, Butterworth, and Klauder (Figure 3).
508 •Wavelet generation
Petrel Geophysics
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Petrel Geophysics
Wavelet generation •509
1 Ricker method A Ricker filter requires only one input - the peak frequency (Figure 4). This filter commonly is used for synthetic modeling.
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seen in the amplitude vs. time spectrum. The Butterworth, Ormsby, Klauder, and Tapered sine filters all have associated side-lobes.
No bandpass filter is involved. The frequency and phase spectrums are purely a function of the peak frequency input. . _ Wavelet _ 1.0-
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Ormsby method The bandpass (Figure 5) of an Ormsby filter can be described using as many as four corner frequencies. Wavelet 1.0-
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Petrel Geophysics
I Figure 6 shows the four Ormsby filter frequencies in Petrel. 100
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1 Low cut frequency, where all lower frequencies are filtered out and not used. 2 Low pass frequency where after this frequency, 1 00% of all higher frequencies is used:
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3 High pass frequency, where frequencies higher than this one are linearly tapered until point 4. 4 High cut frequency, where any frequencies higher than this one are filtered out and not used.
Petrel Geophysics
Wavelet generation •511
I Tapered sine method A tapered sine filter (Figure 7) is defined by a low and a high cutoff similar to a Butterworth filter but applies no further filters. <
A Butterworth filter applies two slopes (refer to the Butterworth method description). Wavelet 1.00 8-
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512 •Wavelet generation
Petrel Geophysics
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Butterworth method The Butterworth bandpass consists of two cutoff frequencies taken at 3 dB down from maximum power, or approximately half power (-50% on the amplitude scale in Figure 8). In the example, frequencies are at 1 0 Hz and 50 Hz. The Butterworth filter also requires two slopes.
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In this equation, X/Y is the ratio of amplitudes. If the ratio of X/Y is 2, it is 6 dB; a ratio of 10 translates to 20 dB (Figure 9).
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Wavelet generation •513
I Klauder method An analytical approximation of the Klauder wavelet is computed through autocorrelation of an actual vibraseis sweep signal. A Klauder wavelet is defined by two frequency cutoff values: a low cutoff and a high cutoff. Figure 10 shows these frequencies set at 10 Hz and 70 Hz.
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A boxcar represents the contributing frequencies. This boxcar assigns the same constant amplitude for all frequency components. Because of sudden discontinuities in the amplitude of frequencies at the beginning and end, the wavelet has some undesirable side-lobe oscillations.
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514 •Wavelet generation
Petrel Geophysics
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Wavelet phase The most important decision that you make when using Petrel is to use either a minimum or a zero-phase wavelet. Dynamite and airgun sources produce impulse (minimum phase) source signatures and the resultant data is not necessarily reprocessed to zero phase.
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Be careful, because the convention for a zero-phase wavelet for the USA and Europe are opposite in phase (Figure 11). Q
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Petrel Geophysics
Wavelet generation •515
I Statistical method The statistical extraction method (Figure 12) assumes that the embedded wavelet is the same as the truncated autocorrelation of the seismic trace. The average autocorrelation from many traces is used to provide a more representative estimate.
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It is possible to access statistical extraction even if no sonic log exists for the borehole. The statistical method transforms the autocorrelation of all of the input seismic traces into the frequency domain, averages the spectra, and inversely transforms the averaged spectra into the phase specified. Such wavelets are zero-phase by definition.
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A statistical wavelet can approximate the correlated source signature used during Vibraseis (non-minimum phase) seismic acquisition. It is useful particularly when the quality of seismic data is high and the quality of the RC series is low.
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516 •Wavelet generation
Petrel Geophysics
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Principles of the Statistical method The statistical methods can be employed as a reliable quality control tool for the deterministic methods, a way of interpolating the wavelet phase between non-matching wells or act as standalone tools in the absence of wells. • Given a borehole trajectory, this method extracts both minimum and maximum values of X and Y: (Xmin,Ymin) and
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(Xmax.Ymax). The auto position (determined automatically) is calculated as the mean between them: ([Xmin+Xmaxj/2, [Ymin+Ymax]/2) It defines the position of the central trace for the extraction. Neighborhood (1x1 , 3x3, 5x5) defines the number of traces to be used for the average.
Figure 13 shows how the statistical method defines the position of the central trace for the wavelet extraction for a given borehole trajectory.
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Petrel Geophysics
Wavelet generation •517
I Deterministic method Deterministic corrections commonly are applied to rectify phase mismatches between final processed seismic data and synthetics created from well logs (Figure 14). For this method, a seismic volume and input logs of interest are required.
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Changing the extraction location automatically updates the extracted wavelet with its corresponding power and phase spectra, as well the resulting synthetic trace. These corrections force the synthetics and seismic to match by assuming that the well logs provide ground truth. However, nearby wells often suggest different phase corrections and well logs are not always available.
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There are two required parameters: • 2D or 3D seismic data and position for wavelet extraction • Input for reflectivity series calculation. fa Wavelet toolbox
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Petrel Geophysics
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Three algorithms for Deterministic wavelet calculation are available in Petrel: • Extended White • ISIS Frequency • ISIS time.
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Extended White Conceptually, the Extended Roy White wavelet extraction method (Figure 15) separates the well tie and wavelet extraction problem into
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these two elements: • Determination of optimal time shift between well log reflectivity and seismic amplitude • Determination of dominant phase. Simply described, the first step is accomplished with a time windowed sliding cross-correlation of the power envelope of the well log reflectivity with the power envelope of the seismic amplitude (both are phase-independent). Optimal time shift from the starting cross¬ correlation point (the optimal lag) is at the maximum cross-correlation point.
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After determining the optimal time shift, the phase of the wavelet used to create the synthetic is rotated until the maximum cross-correlation between the synthetic amplitude and the seismic trace amplitude (both phase-dependent) is found. At this point, the phase rotation from zero is the optimal dominant phase.
The method provides statistics that are useful in judging well tie quality. Optimal is a relative term - both steps of the method are sensitive to the limits of the analysis windows and velocity errors.
Petrel Geophysics
Wavelet generation •519
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General tab From Petrel 2014.3, in an active Well section window, you can use a temporary Time Depth Relationship (TDR) to extract a deterministic wavelet. In previous versions, the TDR had to be assigned to the well to perform the deterministic extraction.
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If a study Well section window is active, the temporary TDR from that window is considered for the deterministic wavelet extraction. Any change from the bulk shift or stretch and squeeze process in the study is used by the Wavelet toolbox for the extraction. The name of the TDR or temporary TDR used for the extraction will be reported at TDR from in the interface. See Figure 16.
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On the General tab (Figure 17), the extraction position can be set at different locations. The number of inlines and crosslines around the center location is specified for 3D seismic data. For 2D seismic data, the center trace and the number of traces on each side define the position. A vertical or deviated well can incorporate this position into the wavelet extraction algorithm.
Petrel Geophysics
Wavelet generation •521
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To position the well to a new location, away from the actual wellhead,
click Set extract position to the deviated well ® . You also can interpolate seismic data to follow the trajectory or click Set extract position to well head
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There is an option to enable or disable the anti-alias filter (used before a signal sampler) to restrict the bandwidth of a signal to satisfy the sampling theorem. This filter is recommended when converting the input logs from depth to time. If you are dealing with synthetic data, it is best to disable this feature.
522 •Wavelet generation
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Petrel Geophysics
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Verticalization tab The Verticalization tab (Figure 18) can merge several different traces due to a deviated well trajectory. This option takes segments from each trace the trajectory crosses and projects them (and merges them) into a single vertical seismic trace, which can then be used for wavelet extraction in a deviated trajectory. General | Verticalization
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Figure 18 Verticalization tab of the Wavelet toolbox
You must use good judgment to determine when a trajectory is so severely deviated that the resulting analysis does not make physical sense. You can control the way seismic data is interpolated using the options Truncated sine function (recommended) and Smoothing in the Verticalization type list.
Petrel Geophysics
Wavelet generation •523
I Taper tab On the Taper tab (Figure 19), you can select the User defined check boxes to customize the length of the taper applied to the cross¬ correlation that is computed and used for wavelet estimation.
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You also can use this tab to define the length of the taper applied to the cross-correlation used for the deterministic wavelet extraction. General
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The default size of the taper is half of the length of xcor, but it can be changed easily by selecting User defined. The percentage of white noise (used to the prevent instability in the calculation of the coherence function) that is added in the wavelet extraction algorithm also can be defined on this tab.
524 •Wavelet generation
Petrel Geophysics
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Extract tab The Extract tab (Figure 20) contains options for setting the time window for the wavelet extraction process and the button that begins extracting the wavelet. |
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After defining the parameters, click Calcúlatelo start the extraction. When the extraction is done, you can change its position interactively by clicking the predictability plots. Changing the position can be useful when there is some question about the true position of the well within the seismic volume.
Petrel Geophysics
Wavelet generation •525
I Output tab In addition to generating wavelets, you can use the Deterministic method to generate the Reflectivity, the Acoustic Impedance, and the Dephase Operator as outputs (Figure 21 ). The Dephase Operator is a special purpose wavelet used to dephase amplitude data. Extended White 1
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Isis time/Isis frequency methods for deterministic wavelets The Isis Time/lsis Frequency methods extract wavelets using reflectivity and seismic data, that is, ISIS Time and Frequency. Which method you select depends on the degree of correlation between the seismic data and the reflectivity log.
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Figure 22 shows the Isis Time and Frequency options in the Wavelet toolbox Q
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Petrel Geophysics
Wavelet generation •527
1 Wavelet extraction displays A PredictabilitysecWon (Figure 23) appears when you set all of the input parameters. Any change in the inputs or in the extraction parameters automatically updates the Predictability.
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Predictability in the Seismic well tie process is used to determine the optimal wavelet. The Predictability section opens automatically and shows the calculated predictability spread in the vicinity of the set extraction point and the wavelet shape. It also shows the corresponding Power and Phase spectra.
528 •Wavelet generation
Petrel Geophysics
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The windows show these Predictability displays: • Maximum Predictability (top view): Calculated correlation between the RC series and the seismic around the well position • Maximum Predictability (side view): Predictability for an inline shown as a function of crossline position and lag time (traces for 2D lines) • Time of maximum predictability: Shows a map of the start time for which the maximum predictability was found. • Phase of maximum wavelet: Shows the phase of the best interval. This option could take considerable time to be calculated. • Predictability information: Data sources, extraction parameters, and predictability values. Initially, a white circle (Figure 24) shows the currently selected wavelet at the maximum predictability of the cube of extracted wavelet. The interpreter can move the extraction point by clicking any predictability display.
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A black X (Figure 24) shows the maximum predictability zone.
The Predictability displays are interactive. By clicking a different location inside a display, the wavelet is updated to the wavelet extracted at that map location and the Predictability for Inline display moves to the selected inline. 1
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Petrel Geophysics
Wavelet generation •529
I Interpret predictability results The predictability and extracted wavelet displays are used together to determine which of many extracted wavelets are the best to use. Sometimes, the optimal predictability does not occur at the exact location of the well.
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When this scenario happens, ask these questions: • Where is the well (truly) located? • Was the well location surveyed correctly? • Is everyone using the same cartographic system? • Were cartographic transforms done correctly? • Are we near the edge of a cartographic zone, where errors are often large? • Is the well deviated? If so, where is the downhole location relative to the surface location? Is • the well cataloged as a vertical hole, but is it slightly deviated?
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Background: Note on predictability information Predictability is calculated using this methodology: An autocorrelation is computed of the Borehole Data and Seismic Data traces Acor1(t) and Acor2(t), and a cross-correlation is computed between them Xcor(t). The
autocorrelations and cross-correlations are tapered from Time zero with a cosine taper up to max-lag samples using:
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530 •Wavelet generation
Petrel Geophysics
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I The global predictability value now is calculated with this equation, based on the tapered autocorrelations and cross-correlations: Predictability
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Predictability values range from 0 to 100, where 100 represents data that matches perfectly. Q
At anytime, these items appear: the maximum predictability map, predictability for a single inline, and the time of maximum predictability or phase of maximum wavelet. The latter two are interactively interchangeable. <
The predictability maps are interactive and linked to the parameters in the Wavelet toolbox. The wavelet for that location is shown and can be edited. The Predictability for an inline window displays the time lag for the position selected in the maximum predictability window. The time of maximum predictability shows the time lag for the best predictability in a map view.
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Use the envelope peak to work out the time lag. Calculate the instantaneous phase at the envelope peak. This calculation is the reported wavelet phase.
The Phase of maximum wavelet display shows the phase rotation for a maximum predictable wavelet for each trace. The phase is determined by calculating the envelope of the wavelet and, from that calculation, the peak of the envelope.
Petrel Geophysics
Wavelet generation •531
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I Predictability and correlation Why use predictability? Predictability is a measure of the similarity of the underlying reflectivity, so it is independent of the wavelet on the seismic. It also is fairly insensitive to amplitude scaling differences and wavelet phase uncertainty between the two time series (Figure 25).
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532 •Wavelet generation
Petrel Geophysics
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Phase manipulation The Seismic well tie process provides comprehensive tools to examine and understand the phase characteristics of the seismic data over a formation of interest.
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To get correct information, it is necessary to interpret events on the correct part of the seismic waveform. Interpreting on zero phase data is important to assure that the Reflection Coefficients (or impedance changes) from the log interpretation match a peak, trough, or zero crossing wavelet character in the seismic. Only by knowing the phase of the data can you reasonably expect to zero phase it correctly.
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Zero-phase seismic data is essential for many geophysical analysis techniques including Seismic Inversion. When the phase of the seismic is understood clearly, the seismic can be reprocessed to apply the dephase operator generated from the Seismic well tie process to the seismic. This action creates a zero phase seismic over the formation of interest (Figure 26).
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For more information, refer to the Stretch and squeeze section in the Synthetic seismogram generation lesson. Operations
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Petrel Geophysics
Wavelet generation •533
I Time shift A bulk shift can be applied to the entire wavelet using the Time shift feature (Figure 27). Operations Phase manipulation| Time shift
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Figure 27 Time shift tab in the Wavelet toolbox
Hanning Filter: Seismic data frequency characteristics Low frequency is not always good. When high frequency features are obscured because of low frequency noise or natural attenuation of higher frequencies, evaluating well tie details can become problematic. When evaluating a well tie, particularly when using a short extracted wavelet or an analytical wavelet (for example, Ricker), keep in mind that the wavelet can be band-limited relative to the seismic and not fully represent low frequency response.
To assist with frequency evaluation, the Hanning filter subtab (Figure 28) is available for all wavelet types in the toolbox. It is a filter option that applies band limiting to the wavelet and to the synthetic traces built using the wavelet. Phase manipulation
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Figure 28 Hanning filter parameters in the Wavelet toolbox
534 •Wavelet generation
Petrel Geophysics
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You can use this feature to evaluate if a wavelet extracted in a deep interval is still applicable in a shallow interval. This feature allows you to filter back the lower frequencies and observe the well seismic tie at a shallower interval.
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You also can use the filter facility to help determine optimal low cut filter parameters to be applied to the seismic data in a later filtering operation. Q
Additional insight into phase behavior is possible because selective filtering allows band-constrained phase behavior to become visible in the wavelet display. Allowing this behavior to become visible is important particularly when working with data acquired with an impulse source (minimum phase). This type of data has the potential for residual minimum phase in lower frequencies after processing.
Scale factor This Scale factor feature (Figure 29) scales the amplitude of the wavelet. For the analytical and statistical normalized method of wavelet extraction in Petrel, the amplitude range varies from -1 to 1. Normally this range does not match the seismic volume's amplitude range. Operations Phase manipulation
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Figure 29 Scale factor tab in the Wavelet toolbox
Petrel Geophysics
Wavelet generation •535
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Lesson 2 (Optional) — Multiwavelet, Multi-well extended white wavelet extraction (MWEW), and Time variant wavelet The Seismic well tie process is entirely integrated with the Petrel platform and supports creation of following wavelets:
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Estimation of an average wavelet calculated from a set of wavelets existing in the project
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One wavelet representing the combination of RCs and seismic traces from all input wells
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Applying existing wavelets over different time intervals to generate a synthetic to address the phenomenon of decreasing frequencies and amplitudes at deeper seismic data
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536 •Wavelet generation
Petrel Geophysics
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Wavelet Average calculates an average wavelet from a set of wavelets that you select. You can define the length and sample interval of the average wavelet, and you can invert the polarity of the resultant wavelet (Figure 30).
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In the Parameters area, you select as input a list of wavelets to be used for the average calculation. You can use Analytical, Deterministic, and Statistical wavelets for the average calculation. The input wavelets can have any sample interval between 1 ms and 16 ms and lengths up to 8 seconds.
The Wavelet Average method automatically computes and plots the result just after the first wavelet is selected as input. It is displayed in dark blue. When all inputs are removed, no wavelet is plotted.
Petrel Geophysics
Wavelet generation •537
I Multi-well extended white wavelet extraction (MWEW) In Petrel 2015.1 a multi-well deterministic wavelet extraction is available. <
One of the key elements for the inversion process is the wavelet. You can extract a wavelet from the seismic volumes using different methods. In Petrel, one of them is the deterministic method Extended White that you can use to extract wavelets for a specific borehole. This method works fine when you are interested in just one well, but in many cases, for inversion, more than one well is available to perform the extraction. Now you have a multi-well option.
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To perform the MWEW, you need an individual deterministic wavelet extraction for every well selected.
MWEW involves these steps: 1. Input: Extended white wavelets where the reflectivity and seismic trace will be retrieved. 2. Extract all wavelets from the same seismic cube. Reflectivity, seismic trace, and time lag used for these wavelets become inputs in the multi-well extraction. Input wavelet amplitudes are not used by this algorithm. 3. Output: Multi-well wavelet extracted. The algorithm uses the extraction window for each one of the input wavelets to get the reflection coefficient (RC) from the logs and the seismic trace from the seismic for all wells. All these pieces from all wells are used to generate just one RC log and one seismic trace log. Between the pieces, a zero interval is added with a length equivalent to the biggest wavelet length.
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The pseudo log and pseudo seismic trace are used to extract a wavelet using extended white given as result one wavelet representing the combination of RCs and seismic traces from all input wells.
See Figure 31 for a schematic diagram for the multi-well extended white wavelet extraction (MWEW)
538 •Wavelet generation
Petrel Geophysics
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Time varying wavelet This tool is useful to address the phenomenon of decreasing frequencies and amplitudes at deeper seismic data. The Time varying wavelet can be useful for applying existing wavelets over different time intervals to generate a synthetic. The character of seismic data varies as time increases, with deeper data generally having lower frequencies and amplitudes. It can be useful to use different wavelets over different time ranges (gates) to generate a synthetic. With the Time varying wavelet option, you can use various existing wavelets and taper types to create a time varying wavelet. Petrel Geophysics
Wavelet generation •539
I This functionality can be accessed on the Input tab on the Seismic well tie dialog box of the Synthetic generation study (Figure 32). >
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When the Time varying wavelet option is selected, the Open time varying wavelet tool button is activated. To launch the Time varying wavelet dialog box, click this button.
In the Time varying wavelet dialog box (Figure 33), you specify time ranges or time intervals over which a series of wavelets can be used to generate the synthetic. You can create as many as ten time ranges represented in a dynamic table. -Hr* Status Wavelet length (ms) Start time (ms)
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Figure 33 Time varying wavelet dialog box 540 •Wavelet generation
Petrel Geophysics
I Each time interval is defined by:
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from the Input pane. When the A wavelet that you insert wavelet is dropped in, the Ul displays its length. The wavelet can be Deterministic, Statistical, or Analytical. If the wavelet is modified, the system displays a warning icon to indicate that the selected wavelet was modified.
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• Start/end times (in ms) for each individual gate (time ranges) over which individual wavelets generate the synthetic. The minimum time interval is 4 ms. Gaps between time ranges are not allowed.
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A taper. The supported taper types are • Trapezoidal • Cosine • Cosine squared • Hanning • Hamming • Blackmann • Papoulis • Minimum energy moment • Minimum amplitude moment
Petrel Geophysics
Wavelet generation •541
I Taper length (Figure 34) is a time in milliseconds over which the gate is gradually smoothed to its edges. This parameter is an integer value with maximum limits of the smallest time range. The value should be a multiple of the wavelet sample rate. If you insert a value that is not valid, it updates the Taper length value automatically to the greater valid value. When the taper is applied, it is centered by the transition between two time ranges with half of the Taper length on each side. The start and end times of the RC log crop the Taper length of the first and the last intervals, respectively.
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I The synthetic generation is performed for each wavelet with the entire RC log. This process results in n different synthetic seismograms (where n is the number of time ranges). These synthetic seismograms are cut to respect the range that you specify, plus half of the taper length in each boundary (Figure 35).
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All the wavelets are resampled to the same sample rate of the one with the lowest sample interval. A synthetic seismogram is generated using the highest resolution.
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Petrel Geophysics
Wavelet generation •543
Exercises — Extract wavelets In these exercises, you extract a wavelet and generate a synthetic seismogram. >
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Exercise workflow 1 . Create a statistical wavelet. 2. Extract a wavelet. 3. Generate synthetic seismograms and compare wavelets.
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544 •Wavelet generation
On the Seismic interpretation domain tab, in the Seismicwell calibration group, launch the Wavelet toolbox.
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I 2. Create a Statistical wavelet with these values: • Length =128 ms • Sample rate = 4 ms • Seismic volume = mig [Realized] 1 • Well = Diamond-14.
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3. Try different wavelet parameter values: • Length • Sample rate • Neighborhood • Taper • Regions (Position, Inline, Xline, Start time. End time) • Operations (Phase manipulation). The wavelet displayed in the dialog box updates automatically based on any change that you make. 4. When you are satisfied, click Apply and click OK. The wavelet is saved and stored at the bottom of the Input pane. Petrel Geophysics
Wavelet generation •545
I 5. Drag this newly created Statistical 1 wavelet into the Wavelets folder. 6. You again can view or edit the newly created wavelet. Expand the Wavelets folder in the Input pane, right-click Statistical 1 wavelet, and select Open in wavelet toolbox. * C Wavelets
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546 •Wavelet generation
Petrel Geophysics
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Exercise 2 — Use wavelets interactively for a quick synthetic analysis The interactivity of the Seismic well tie process allows quick analysis of a synthetic by using a wavelet for initial assessment. 1. As explained in the previous exercise, create a Synthetic generation study in the Seismic well tie dialog box. 2. Choose the newly created wavelet. 3. Open the Wavelet toolbox from the Seismic well tie dialog box. m 0
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Wavelet generation •547
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548 •Wavelet generation
Petrel Geophysics
I In the Wavelet toolbox, use the options available in the Operations section to edit the phase and time of the wavelet. 5. Select the Autosave option to save the wavelet and interactively observe the updates in the synthetic when changes are applied. 4.
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3. Select Diamond-14 from the Well list or insert “v* . 4. Select the mig [Realized] 1 seismic cube from the corresponding field. 5. By default, the extraction position is set automatically to the well location. Because the well has a deviated trajectory, click Set extraction position to the deviated well . This button sets the reference center point at the inline/ crossline location where the TWT of the trajectory matches the Petrel Geophysics
Wavelet generation •549
I TWT at the midpoint of the extraction window. 6. Specify (in the number of inlines and crosslines) an area around the defined position where it is possible to perform wavelet extraction. The predictability between the seismic trace and the RC series will be calculated. 7. For the RC calculation method, choose the Acoustic impedance named Al that you created in previous exercises. It is stored in the (Study ...) Diamond-14 Synthetic generation folder in the Global well logs folder. 8. On the Extract tab, set a start time and window length to define the area of extraction for the wavelet. The interval of interest should be the reservoir interval. You can keep the default value (it uses the whole interval with data). Consider a synthetic to be a valid representation only within the interval from which the wavelet was extracted. After you have configured all of the necessary settings for the extraction to take place, the wavelet is created virtually. The Extracted wavelet display and Predictability display windows are populated. The Predictability display window is divided into five parts: • Maximum predictability (top view): Color-coded display of the maximum predictability in the various inline and crossline positions. • Maximum predictability (side view): Based on the selected inline position in the maximum Predictability display, predictability is color-coded as a function of crossline position and time lag (between seismic and RC series). • Time of maximum predictability: Color-coded display of the lag time for maximum predictability in the various inline and crossline positions. • Phase of maximum wavelet: Color-coded display of the wavelet phase for maximum predictability in the various inline and crossline positions • Predictability information: Values for the current selected extraction position.
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Petrel Geophysics
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Petrel Geophysics
Wavelet generation •551
I 12. In the left part of the Wavelet toolbox dialog box, open the Wavelet list by clicking an arrow, indicated by a circle in the figure. 13. In the left part of the Wavelet toolbox dialog box, insert 'v* the other wavelets. 1 4. Click the check boxes to select these wavelets for comparison.
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I 15. In the Wavelet display option section, click the Relative Amplitude check box to compare the power, phase, and amplitudes of the wavelets. Wavelet
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16. Create three synthetic seismograms using the three wavelets and compare the results. Refer to the Synthetic generation lesson exercises. 17. Use the Auto save option in the Wavelet toolbox to see changes in the output synthetic seismogram quickly.
Petrel Geophysics
Wavelet generation •553
1 0
Exercise 4 — Create an Integrated Seismic well tie study 1 . Run a new Integrated Seismic well tie study. a. Continue to work with Diamond-1 4. b. Define the parameters using the same process from the previous exercise and in the Sonic Calibration lesson exercises. c. Choose the type of wavelet. 2. On the Output tab: a. Select TDR: Calibrated sonic. b. Select the Autosave check box. c. Click the Set as active TDR button.
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554 •Wavelet generation
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Petrel Geophysics
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I 3. Click Apply. An integrated Well section window opens where you can perform Sonic Calibration as well as Synthetic Generation.
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Calibrate the sonic. Pick individual knee points with a checkshot update and observe the change in the synthetic after each pick. This calibration helps you to identify which checkshot knee points have the most influence over the final depth-time relationship. It also provides insight into which borehole intervals are responsible for the greatest velocity updates. 5. Stretch and squeeze the synthetic. You can output the new time-depth relationship (after stretching and squeezing) and select it on the Time tab of the well Settings dialog box to use it. However, if you used an extracted wavelet, remember to extract it again after the new time-depth relationship has been changed. Perform this task after changing the time-depth relationship, even though the synthetic window reflects these changes. 4.
Petrel Geophysics
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Because the time-depth relationship in the sonic calibration and synthetic generation are linked, any change made in the sonic calibration is reflected automatically in the synthetic.
Wavelet generation •555
I 9
Review questions
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• Q
What is meant by Analytical, Statistical, and Deterministic methods of wavelet creation/extraction? Is it correct that Ricker, Ormsby, Tapered Sine, Butterworth, and Klauder are Analytical types of wavelets? Are they available in Petrel? Can you create, import, or export a wavelet in Petrel? If yes, how?
Summary In this module, you learned about: • using the Wavelet toolbox • creating different types of wavelets by usinq Analytical,
556 •Wavelet generation
Petrel Geophysics
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