What`s New in GeoX 6

Transcription

What’s New in GeoX 6
July 2013
Contents
INTRODUCTION.................................................................................. 3
EXTENSIONS AND ENHANCEMENTS ............................................ 3
SHARED FACILITIES ............................................................................... 3
Simpler SI unit labels for rock volumes............................................. 3
Total liquid and gas volumes ............................................................ 3
Active management of entitlements ................................................... 3
Excel templates in DB ...................................................................... 3
Resource diagram and PDF in scenario analyses ............................. 3
Direct launch of analysis .................................................................. 4
Faster save/open of analyses ............................................................ 4
Sharing data with other applications via External tables .................. 4
SEGMENT ANALYSIS TOOL ..................................................................... 4
Saturation Height Function .............................................................. 4
Dual Porosity ................................................................................... 4
Alternatives for well spacing ............................................................ 4
Recovery factor for direct field size model ........................................ 4
New Bayesian Risk Modification Procedure ..................................... 4
PROSPECT ANALYSIS TOOL .................................................................... 5
Merge of prospect analyses .............................................................. 5
Documentation of risk dependencies................................................. 5
DFI dependency ............................................................................... 5
Distribution of number of segments in success case .......................... 5
Prospect analysis Excel report with info on enrolled segments ......... 5
PLAY ANALYSIS TOOL ........................................................................... 5
Recovery factor for direct field size model ........................................ 5
Shale gas, CBM and dual porosity plays........................................... 5
RESERVE TRACKER ............................................................................... 6
Project based classification .............................................................. 6
Mixed deterministic and stochastic classification ............................. 6
FULL CYCLE ANALYSIS TOOL ................................................................. 6
Production only ................................................................................ 6
Direct entry production profiles ....................................................... 6
Explicit modeling of water handling facility ..................................... 6
Type well templates .......................................................................... 6
Relabeled and new cash flow results................................................. 6
HC outcome tree .............................................................................. 6
Nominal, real and success case results ............................................. 7
EUR/well in Summary results ........................................................... 7
New folder for Full cycle templates .................................................. 7
Fiscal regime attachments ................................................................ 7
Excel reports .................................................................................... 7
PORTFOLIO ANALYSIS TOOL................................................................... 7
GeoKnowledge
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What’s New in GeoX-6
Production only portfolios ................................................................ 7
Bubble chart portfolio composition .................................................. 7
USING THE EXTENSIONS AND ENHANCEMENTS ...................... 8
SHARED FACILITIES ............................................................................... 8
New SI unit labels for rock volumes .................................................. 8
Total liquids and gas volumes .......................................................... 9
Resource diagram and PDF in scenario analyses ........................... 10
Active management of entitlements ................................................. 15
Excel report templates in GeoX database ....................................... 20
Launch GeoX from Command Line................................................. 25
External Table Lookup on MS SQL Server...................................... 26
SEGMENT ANALYSIS TOOL .................................................................. 27
Recovery factor with direct total volume model .............................. 27
Well spacing and well density ......................................................... 29
Saturation Height Table/Function .................................................. 32
Dual Porosity ................................................................................. 41
New Bayesian Risk Modification Procedure ................................... 48
PROSPECT ANALYSIS TOOL ................................................................. 57
Merge of prospect analyses ............................................................ 57
DFI dependency ............................................................................. 63
About Number of segments discovery ............................................. 66
Excel report on segments in a Prospect analysis............................. 67
FULL CYCLE ANALYSIS TOOL ............................................................. 71
Production-only full cycle models................................................... 71
Direct entry production profiles ..................................................... 75
New folder structure for Full cycle templates ................................. 79
Well types templates ....................................................................... 81
Excel reporting – FullCycle analysis .............................................. 91
Overview of report template mapping alternatives .......................... 94
RESERVE TRACKER ............................................................................. 97
About RT and How to Use RT ......................................................... 97
Copyright © 2013 GeoKnowledge
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Introduction
GeoKnowledge continues to deliver: Release 6 adds a significant number
of new functions to GeoX. There are several main enhancements: New
segment analysis options for handling dual porosity assets and for
modelling saturation height, a new prospect merge function to do mega
prospects, extensions and enhancements of the full cycle tool, and a new
Project-Asset-Entitlements Reserve Tracker (RT) that combines stochastic
and deterministic classifications. There is also a new ArcGIS add-in that
supports map-based assessment at both the segment/prospect level and the
play level.
Note that some of the enhancements are minor, but are listed as they
potentially have consequences for assessed results.
Extensions and Enhancements
Shared facilities
Simpler SI unit labels for rock volumes
Reporting of rock volumes in SI has been simplified. Units are now in
million m3. This corresponds to the earlier km2-m units used for rock
volumes in SI.
Total liquid and gas volumes
Want an estimate of combined volumes of free gas and associated gas
and/or an estimate of the combined volumes of oil and condensate
associated with the free gas? Trial-by-trial estimates of total liquids and
total gas are now provided in the results section of all analyses (segments,
prospects, full cycle, portfolio value).
Active management of entitlements
A new Entitlements functionality provides a common platform for license
information that serves both assessments and Reserve Tracking You can
now maintain a complete history of license information with versioning
and automated updates of analyses or assets that reference license
information.
Excel templates in DB
There is no longer any issue with accessing Excel templates when running
GeoX over Citrix. The templates can be stored in the GeoX database and
then directly accessible by all users.
Resource diagram and PDF in scenario analyses
The new stochastic simulation improves the reporting in multiple scenario
analyses. A resource diagram shows the contribution of the different
scenarios to the success case volumes. All results now have probability
distributions in addition to exceedance probability curves.
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Direct launch of analysis
Build applications where the application can open a GeoX analysis. Users
can for example select a segment in a map context, and the application can
launch the corresponding segment analysis.
Faster save/open of analyses
New storage strategies provide much faster analysis save and open. The
improvements are most evident in analyses with a large number of
enrolled analyses or in full cycle analyses with significant project duration
and result categories.
Sharing data with other applications via External tables
Have GeoX-relevant data in other databases? The GeoX external table
lookup function is now also available with SQL Server. The functionality
facilitates using external data in GeoX without needing to replicate the
data in the GeoX database.
Segment analysis tool
Saturation Height Function
Are you assessing low porosity or low relief structures? The new
saturation height functionality lets you capture the effects of transition
zones on average saturation. Use either direct entry of a saturation height
table or a lambda-type function to model the combined effects of height
above water contact and average reservoir porosity.
Dual Porosity
Single segment implementation of dual porosity makes analysis both faster
and less error prone. Intermediate results indicate matrix and fracture
volumes for immediate verification of results.
Alternatives for well spacing
Well spacing in the EUR/well recovery model can now either be defined
as area per well or as number of wells per unit of area.
Recovery factor for direct field size model
You can now get estimates of in-place volumes when using the direct total
field size volume model. By entering an estimate of the recovery factor,
the system calculates the corresponding in-place volumes.
New Bayesian Risk Modification Procedure
The existing Bayesian Risk Modification (BRM) procedure for handling
seismic anomalies (DFI’s) has been extended to produce estimates of the
BRM chance estimates.
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Prospect analysis tool
Merge of prospect analyses
Build rapidly analyses of multiple prospects by using the new merge
capability. You can enrol multiple prospect analyses in a single prospect
analysis. Enrol merges the different prospect analyses with all their
dependency, correlation and leak definitions. The resulting analysis of the
“mega” prospect can be edited with all the functionality of the standard
prospect analysis.
Documentation of risk dependencies
Improve definition and interpretation of risk dependency estimates with
presentation of resulting estimates of conditional risks given estimates of
probability of shared geological controls and the basis for the estimates.
DFI dependency
A new DFI dependency concept complements the enhanced Bayesian Risk
Modification procedure at the segment level. DFI dependency groups
with associated correlation can be used to model the amount of
information provided by seismic anomalies on multiple segments in a
prospect. Prospect analyses with DFI can now be run with full cycle
analyses and can be aggregated.
Distribution of number of segments in success case
A new result report provides the basis for summarizing key results in
prospects with a large (> 5) number of segments. The relative frequency
of number of success case segments complements the information
provided by the joint segment probability table.
Prospect analysis Excel report with info on enrolled
segments
It is now possible to make a prospect analysis report that includes all
properties, inputs and results needed from segment analysis enrolled in the
prospect analysis.
Play analysis tool
Recovery factor for direct field size model
the system calculates the corresponding in-place volumes.
Shale gas, CBM and dual porosity plays
Want to do a play-level assessment of resource play fairways? Want to
assess a play with dual-porosity features? The play tool has been extended
to include shale gas, CBM and dual porosity models for the postulated
features in the play.
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Reserve tracker
Project based classification
Classifications are now 100% project based where by definition all
resources in a project belong to one resource class. RT provides three
inter-related views: Projects, Assets and Entitlements.
Mixed deterministic and stochastic classification
You can now combine stochastic classification and deterministic
classification in one classification model. For example, prospective
resources can use stochastic classes while contingent resources and
reserves can use deterministic classes. Resources are booked on projects
in a project-assets-entitlements framework.
Full cycle analysis tool
Production only
Do rapid and simple modelling of full cycle projects where you do not
need to enter cost and fiscal data. The system produces estimates of
production related results (profiles and summary performance indicators).
Direct entry production profiles
Need to use production profiles prepared outside of GeoX? Want to make
a field model that does not follow the standard buildup-plateau-decline
format? The new direct entry type well lets you paste in a production
profile package (main and associated products and water).
Explicit modeling of water handling facility
Water handling capacity and cost are potentially important full cycle
evaluation considerations. A new water development component – that
complements the existing liquids and gas components -- is now available
to model these elements.
Type well templates
Well definition in production activities typically involves representative
type wells. The new well template functionality provides a powerful
functionality for managing and sharing type well definitions.
Relabeled and new cash flow results
The label for CAPEX sum for development activities has been renamed
for greater clarity. In addition, development cash flow results at the
activity level make it possible to track the active values in the trial
browser.
HC outcome tree
A new Outcome tree in the Project section gives outcome estimates in
terms of HC reserves and complements the NPV Decision tree in the
Contractor section.
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Nominal, real and success case results
Summary stochastic performance indicators have been expanded to
capture both nominal, real and success case performance (NPV, PI, IRR).
Differences reflect your definition of discount rates, HC product price
scenarios and inflation rate scenario.
EUR/well in Summary results
Summary results report on key performance indicators. These indicators
have been extended to cover EUR/well statistics.
New folder for Full cycle templates
For more effective management of Economic scenario, Fiscal Regime and
Well type templates these can now be organized in folders with at multiple
levels. This opens for a more detailed and customizable sub-division that
again allows a better use of the Approve functionality for the templates.
Fiscal regime attachments
Complete description of fiscal regime model assumptions is key, A new
fiscal regime attachment functions supports full documentation with
supporting documents in the GeoX database.
Excel reports
Make your own custom full cycle analysis reports. The Report template
editor has been extended to support custom Excel reporting of both
summary data and profiles in full cycle analyses.
Portfolio analysis tool
Production only portfolios
The new “production only” full cycle modelling is complemented with a
“production only” assessment of your exploration portfolio. Let’s you
focus on how well the portfolio can achieve your production goals.
Bubble chart portfolio composition
Want to check the composition of your portfolio? The bubble chart result
diagram gives a quick overview of the projects in the portfolio in terms of
chance of success, resources and NPV.
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Using the Extensions and Enhancements
Shared facilities
New SI unit labels for rock volumes
Reporting of rock and pore volumes in SI has been simplified. Units are
now million m3. This corresponds to the earlier km2-m units used for rock
and pore volumes in SI.
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Total liquids and gas volumes
Trial-by-trial estimates of total liquids and total gas are now provided in
the results section of all analyses (segments, prospects, full cycle, portfolio
value).
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Resource diagram and PDF in scenario analyses
The new stochastic simulation improves the reporting in multiple scenario
analyses. A resource diagram shows the contribution of the different
scenarios to the success case volumes. All results now have probability
distributions in addition to exceedance probability curves.
About the Setup page
The Setup Analysis page is used to set up the procedure for estimating
resources and risks for the multiple scenario analysis.
Sample size [selection list or integer number] defines the number of
success case trials to be included in the Monte Carlo simulation.
Use initial seed [check] determines if the Monte Carlo simulation is to use
the seed defined in the initial seed number box.
Initial seed number box [integer] defines the initial seed used when use
initial check box has been checked.
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About the Definition of the Scenario Set
The Definition page is used to define the scenario set. The scenario set is a
complete, mutually exclusive set of scenarios for the prospect (segment).
A full scenario set includes both a prospect (segment) analysis of risks and
resources and a full cycle analysis of the associated full cycle value of the
prospect (segment). A partial scenario set focuses risk and resource
assessments of the scenarios in the scenario set.
The scenario diagram displays the probability density function for each
scenario as well as for the probabilistic aggregate. There is a display for
each phase and for total resources (in OE/GE). You switch between the
displays by selecting the appropriate dial buttons. The minimum volume
and screening threshold volumes for each scenario is also displayed on
the OE/GE resources scenario diagram.
Note
•
If the scenarios are not calculated, then the scenario diagram is empty.
The scenario definition table shows the scenario attributes for each
scenario as well as any multiple scenario attributes that apply for the set.
Add used to enrol scenarios. The system opens a selector dialog on the
segment (prospect) analyses. Check the analyses to be included. Check
also attached full cycle analyses to get a complete scenario set.
on a scenario in the scenario definition table to enter weight
estimates. The scenario weights need to sum to 1.0.
Double click
Remove
removes the selected scenario.
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opens the selected scenario analysis. It can be edited and the edits
can be saved. The multiple scenario analysis uses the edited version of
the analysis even if it is not saved.
Edit
Normalize
to normalize scenario weights so that they add to 1.0.
Add deterministic is used to enrol deterministic scenario that will be
displayed on the success details results. The system uses the mean results
for the deterministic scenario.
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About the Resource Diagram
The resource diagram provides a graphical picture of the composition of
the success case exceedance probability curve for the total recoverable (inplace) hydrocarbon resources [in OE or GE] in the prospect (segment).
There are three alternative representations: by total resources for each
prospect (segment) scenario, by HC products for the prospect (segment),
and by HC products for each prospect (segment) scenario.
Notes
•
The color bars are based on 100 trials in the Monte Carlo simulation
used to produce the estimates. The trials are evenly spaced after all
trials have been sorted in ascending order according to total resources
in OE or GE. For example, with a simulation run with 500 trials the
diagram displays the composition of total resources for every 5th trial.
•
The estimates in the Legend section (in square brackets) show the
success case mean estimates. In the case of the "by sceanrios" view,
the mean estimates are for the success outcomes for the scenario. To
see the basis for the estimate for each sceanario, select the resource
table view. Sample size for each scenario is typically less than the
sample size for the number of prospect success trials.
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About Net Present Value
The net present value page shows the success case net present value (NPV)
for each prospect (segment) scenario as well as the overall success case
NPV.
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Active management of entitlements
A new Entitlements functionality provides a common platform for license
information that serves both assessments and the ReserveTracker. You
can now maintain a complete history of license information with
versioning and automated updates of analyses or assets that reference
license information.
About the Entitlements tab
Used to create and manage nations, blocks and licenses. The entitlements
(licenses) are organized in a nation-region-block hierarchy.
The right-hand pane Summary tab shows summary information (name,
start date, end date and owner interest) on licenses in the selected item in
the nation-region-block-license tree browser in the left-hand pane.
The Analysis tab shows the assessment analyses associated with the
selected nation-block-license entity. The Assets tab shows the assets
(defined in the ReserveTracker) associated with the selected entity. The
History tab shows changes to licenses in the selected entity.
Right-click on entitlement objects (nation, block, license) to Add, Edit
and Delete.
For Help on the GeoXplorer commands see also About the GeoXplorer
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About the Analyses tab (Entitlements)
A table with iinformation on the segments (analyses) that are in licenses
associated with the selected entity in the Nation-Block-Region-License
hierarchy.
For each analysis (row) in the analysis overview table, there is the analysis
name, the assessment context (basin, play, segment), analysis type, the last
modified date, the user who modified it and the analysis ID.
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About the History tab (Entitlements)
A table with a log of license information changes for licenses associated
with the selected entity in the Nation-Block-Region-License hierarchy.
Change records are used to verify that license information in analyses is
up-to-date.
Each change record lists the change date, the user-id of the user that did
the change and a description of the updated license data.
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About Edit Licenses
Used to edit the licensee information and define the blocks that the license
belongs to. The licensee information with the link to the relevant set of
blocks is best maintained in the Entitlement section (tab) of the
GeoXplorer. The information is shared with the ReserveTracker.
Changes are automatically recorded for use in verification of entitlement
status in the segment analyses.
There are four (4) descriptive attributes:
Label is the license identifier
Start date is the date that the license was started.
End date is the date that the license is terminated.
Area is the areal extent of the license.
There are three sub-panels: Licensee, Description and Blocks.
The fields in the Licensee sub-panel are:
Licensee is the name of the licensee.
WI Exploration is the licensee interest in the exploration phase.
WI is the licensee interest in the production
Net is the net interest factor. Net interest = WI x Net
Owner identifies the licensee entry to be used in the WI and Net
calculation.
Operator identifies the licensee that is the operator of the license.
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Blocks defines the blocks to which the license belongs
Description [text] is used to document the license
Notes
•
•
Start date, end date and area is for documentation only. It is not used
in any calculation.
WI exploration and Operator information is for documentation only. It
is not used in any calculation.
Buttons to the right of the licensee sub-panel
Add adds another licensee
Delete deletes the selected licensee
Close closes the Edit licensees
Buttons to the right of the blocks sub-panel
Add opens the block selector for adding a
Remove deletes the selected block
block to the license
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Excel report templates in GeoX database
Excel templates can be stored in the GeoX database and are then directly
accessible by all users.
GeoX Excel reporting facilitates reporting data from an active analysis.
The report is defined using the Reporting template editor tool. The GeoX
template defined in the Reporting template editor tool establishes the
mapping between the active analysis variables and a user defined Excel
template.
The mapping process creates a link to all aspects of the analysis and the
Excel report: input parameters, risk factors, properties, intermediate results
and final results.
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About the Report template editor
The Report template editor is the link between the GeoX analysis and the
Excel report template. The Editor is used to define the mapping between
the analysis and the Excel template.
The Report template editor supports Excel reports for the following
analysis types: segment analysis, dry analysis, discovery analysis, prospect
analysis, full cycle analysis and multiple scenario analysis.
Report templates show the list of the report templates that have been
defined in the system. Double clicking on the template opens the report
template editor in Edit mode on the selected template.
File > New is used to select the type of analysis handled by the report
template
File> Export is used to export Report templates
Edit> Edit template is used to edit the selected template
Edit> Delete template is used to delete the selected template
Edit> Copy template is used to make a copy of the selected template
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About the Report template editor – edit mode
The edit mode of the Report template editor is used to define the mappings
between aspects (variables, properties, attributes) of an active analysis and
the template Excel report.
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•
•
•
Template name is the name of the report template. The name will
appear in the File>Print option of the analysis.
Template file is the name of the template Excel report file.
Unit settings define the units used in the Excel report. Unit
settings are defined in the same panel as used in the GeoX
analyses.
Analysis type is the analysis type for which the report template has
been defined.
Template mappings are the mappings to the template Excel report
for the analysis aspects
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About Template file editor
The Template file editor is for defining the excel file that will be used as
the basis for the analysis report.
An Excel file can be searched in a physical address (Local folder or public
server) using the option Select file from URI as it was done in previous
GeoX versions. Templates can also be saved directly in the GeoX
database. The latter assures access in a Citrix environment.
First add the Excel template to the data base using the Add template file to
database command. The template in the data base can be edited. It is
also available in the Template file editor.
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The comment field is used to document the templates in the GeoX
database (see above).
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Launch GeoX from Command Line
Build applications where the application can open a GeoX analysis. Users
can for example select a segment in a map context, and the application can
launch the relevant corresponding segment analysis.
About Launching GeoX from Command Line
Launching a new GeoX instance and open analysis with id from command
line works with the following syntax:
visual.exe geox.im -analysis # -automaticLoginDefaultProfile
where
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# is the analysis ID
-automaticLoginDefaultProfile is a swith
The -automaticLoginDefaultProfile switch can be omitted
from the command.
A user will automatically be logged in to GeoX without having to click the
OK button if the -automaticLoginDefaultProfile switch is
included. The user will be logged in with the default GeoX profile and it
requires that the Save password to personal INI file option is turned on, or
that Windows Authentication is used.
If GeoX is located in a folder called C:\Program Files (x86)\geox6\ and the
ID if the analysis you wish to open is 7 then use the following command
line:
"C:\Program Files (x86)\geox6\visual.exe"
"C:\Program Files (x86)\geox6\geox.im" -analysis 7
-automaticLoginDefaultProfile
This launches GeoX and opens the analysis:
Note
•
When using Windows authentication GeoX will be launched without
asking for a username and password. If you are not using Windows
authentication, then the user will be asked to enter username and
password before logging in.
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External Table Lookup on MS SQL Server
Have GeoX relevant data in other databases? The GeoX external table
lookup function is now also available with SQL Server. The functionality
facilitates using external data in GeoX without needing to replicate the
data in the GeoX database. The facility can also be used for linking
Properties in GeoX to external tables.
About External Table Lookup
Enable the External table lookup from the System menu in GeoXplorer.
You have the option of choosing between SQL Server and Oracle as
database type.
Select the External data type (Nation, Block, License, BlockLicense,
Region, Chronostratigraphy, Lithostratigraphy, and Data Source 1 to 5).
Then select Database type (Oracle or SQL Server), check the Enable box,
and fill in the Lookup details.
The parameters in the Lookup details depend on the data type. The
external table you are connecting too needs to have the required columns.
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Segment Analysis Tool
Recovery factor with direct total volume model
the system back-calculates the corresponding in-place volumes on a trialby-trial basis.
The Setup of the Fluids page does not give any choice in terms of recovery
model (it has to be Recovery factors).
About Fluids Input Parameters for direct total resources
The Fluids page defines, together with the Volume page, the main inputs
for estimation in-place and recoverable resources at surface conditions.
The active fluids parameters are defined on the Fluids Setup page.
Gas Oil Ratio [Sm3/Sm3 or scf/STB] is the associated gas to oil ratio.
Condensate Yield [Sm3/million Sm3 or STB/million scf] is the yield of
condensate from wet gas.
Recovery Factor Oil [fraction or %] is the amount of oil in-place that can
be recovered.
Recovery Factor Assoc. Gas [fraction or %] is the amount of associated
gas in-place that can be recovered.
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Recovery Factor Gas [fraction or %] is the amount of in-place nonassociated gas that can be recovered.
Recovery Factor Condensate [fraction or %] is the amount of condensate
in-place that can be recovered.
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Well spacing and well density
Well spacing in the EUR/well recovery model can now either be defined
as area per well (well spacing) or as number of wells per unit of area (well
density).
In short, well spacing (area per well) = 1 /well density (wells per unit of
area).
For example, with a well density of 5 wells per km2 the corresponding
value for well spacing is 1/5 or 0.2 km2 per will.
About Fluids Setup
This page is used to select among the alternative representations of the
parameters that define HC resources at surface conditions as well as
associated products and recovery of hydrocarbons.
Fluids parameter models
This section is used to select between depth independent and depth
dependent definition of fluid parameters. With the depth dependent
definition, oil formation volume factor (Bo), gas formation volume factor
(Bg), the Gas Oil Ratio (GOR) and the condensate yield (CGR) are
modelled as a function of a stochastic reservoir depth estimate.
Formation factors and recovery factors.
There are two approaches to modelling parameters:
1. Direct entry of GOR, oil formation volume factor (Bo) or oil shrinkage
factor (1/Bo),and direct entry of either gas formation volume factor
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(Bg) or gas expansion factor (1/Bg) as well as the recovery factors for
all hydrocarbon phases.
2. Indirect calculation of gas expansion, oil shrinkage and GOR from
pressure, temperature, and gravity. There is a sub-option to calculate
non-associated gas recovery factor from initial and abandonment
pressures.
With direct entry of formation volume factors, you can select whether to
use oil formation volume factor (Bo) OR use oil shrinkage factor (1/Bo).
You can separately select whether to use gas formation volume factor (Bg)
OR gas expansion (1/Bg).
Wet Gas Shrinkage
Used to model the change in the non-associated gas volume that occurs
when condensate is extracted from the gas flow-stream. There are two
alternative methods:
1. Direct entry of wet gas shrinkage factor.
2. Indirect calculation of the wet gas shrinkage factor as a function of
condensate yield.
Indirect calculation of wet gas shrinkage factor uses a proportionality
constant, Condensate Extraction Factor, to compute wet gas shrinkage as a
function of Condensate Yield:
Wet gas shrinkage = (1 – (Condensate Yield / Condensate Extraction
Factor)).
Dry Gas Shrinkage
This option is available when computing NGL, dry gas, and non-sales gas.
It is used to model the change in the associated and non-associated gas
volumes that occur when NGL is extracted from the gas flow-stream at a
gas plant. There are two alternative methods:
1. Direct entry of dry gas shrinkage factor.
2. Indirect calculation of dry gas shrinkage based on NGL yields.
Indirect calculation of dry gas shrinkage uses a proportionality constant,
NGL Extraction Factor, to relate dry gas shrinkage to NGL Yield.
Dry gas shrinkage = (1 – (NGL Yield / NGL Extraction Factor)).
Recoverable resources
There are two alternative methods for estimating recoverable resources
1. From in-place volumes, with recovery factors for each product.
2. From EUR (estimated ultimate recoverable) / well with an estimate of
number of wells
Number of wells can be defined using two alternative methods:
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1. Wells density - number of wells per unit of area (per km2 or per 1000
acres)
2. Well spacing - space per well (km2 or acres)
Secondary Recovery Factors.
This option is available discovery analyses. The factors are used to model
secondary recovery volumes.
Notes
•
There are 6 depth related fluid parameters:
Original reservoir pressure (Pe) [bars or psi]
Reservoir temperature (T) [Deg K or R]
Gas-Oil Ratio (Rs) [ sm3/sm3 or scf/STB]
Oil Formation Factor (Bo) [sm3/sm3 or bbl/STB]
Gas Compressibility (Z) [real]
Condensate Yield (C) [sm3/1000 sm3 or STB/1000 scf]
These variables are modelled as a function of depth using one of four
different functional forms: Zoned linear, exponential, power and logarithmic.
Each function is expressed using two parameters A and B that describe the
depth gradient (A) and a constant (B). In the zoned linear there is a depth
parameter in addition to the A and B parameters for each zone.
Depth floor [m or feet] is an estimate of at what depth oil cracks into gas. It is
used to estimate the probability that the depth of reservoirs are below the
depth floor. This latter estimate affects the relative probability of oil and gas
accumulations.
•
•
Indirect calculation of oil shrinkage and GOR uses Standing
correlations. Inputs are saturation pressure, oil gravity, associated gas
gravity, and reservoir temperature.
Indirect calculation of gas expansion uses the Drunchuk-PurvisRobinson method to interpolate the Standing-Katz Z-factor curves.
Inputs are initial reservoir pressure, non-associated gas gravity, and
reservoir temperature. See calculation of Bg for details
.
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Saturation Height Table/Function
Are you assessing low porosity or low relief structures? The new
saturation height functionality lets you capture the effects of transition
zones on average saturation. Use either direct entry of a saturation height
table or a lambda-type function to model the combined effects of height
and reservoir porosity.
About Volume Setup
This page is used to set up the options for alternative approaches to
modeling hydrocarbon pore volumes.
In addition to direct entry of estimates of hydrocarbon volumes (either for
each of the HC phases that might be active or in OE terms), there are four
basic (not depth dependent) approaches to estimating net rock volumes
where you enter:
•
•
•
•
Direct estimate of Net Rock Volume (NRV)
Direct estimate of Gross Rock Volume (GRV) and the Net/Gross ratio
Area of closure, reservoir thickness, a geometric factor and the
Net/Gross ratio
Area of closure, reservoir thickness, column height, closure length-towidth ratio, closure flat-top ratio and the Net/Gross ratio
There are five depth-dependent approaches where you enter estimates of
the Net/Gross ratio and:
•
•
A function that describes the relationship between depth and Gross
Rock Volume (GRV)
Reservoir thickness and a function that describes the relationship
between depth and closure area at top of reservoir
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July 2013
•
•
•
A function that describes the relationship between depth and closure
area at top of reservoir as well as reservoir thickness
area at top of reservoir as well as reservoir thickness. Reservoir
thickness is entered as constants. Uncertainty in reservoir thickness is
defined using a thickness uncertainty multiplier (TUM)
area at top of reservoir as well as closure area at base of reservoir
In addition to the direct specification of depths, there is an option for
indirect specification of depths using column heights. When using indirect
(column height) specification there is a need to enter the depth of the crest
of the structure.
In addition to the estimate of Net Rock Volume under closure, there is a
need to indicate how much of this volume is filled with hydrocarbons in
order to calculate the hydrocarbon pore volume.
In the non-depth dependent approaches, you enter an estimate of the
percentage of the Net Rock Volume under closure that is filled with
hydrocarbons (trap fill). In depth dependent methods you enter the HC
water contact (HCWC) depth as well as the depth of the closure’s spill
point .
In cases with multiple HC phases, you also need to indicate either the
share of HC pore volume that is free gas (non-depth dependent) or the gas
oil contact (GOC) depth (depth dependent with direct depth estimates).
For the case of indirect depth (column) specification, the alternative to
indicating the height of respectively the oil and the gas column is to enter
an estimate of the HC column height and the gas fraction of the HC
column.
The Net/Gross Ratio Estimation option is used to define whether the netto-gross ratio is entered directly or using two parameters. For the two
parameter selection, the input will be Net sand fraction (the fraction of the
GRV that is sand facies) and Net reservoir fraction (the fraction of the
sand that is of sufficient reservoir quality).
The Yield Estimation option is used to define whether a yield estimate is
entered directly or is calculated using estimates of porosity, saturation (and
trap fill).
You can either enter directly an estimate of average oil and gas saturation
or indirectly with an estimate of how water saturation varies above the
height hydrocarbon water contact.
The depth dependent HC pore volume parameter options determine
whether net-to-gross, porosity and saturation can vary with depth.
Note
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July 2013
•
•
The depth dependent HC pore volume modeling options are only
available when you have selected modeling options that include
explicit modeling of depth dependent volumes or areas.
The depth dependent saturation modeling option is not available when
using the indirect definition of how water saturation varies with the
height above the water contact.
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July 2013
About Saturation Height Table page
Modeling option where saturation is a function of height above
hydrocarbon water contact. In the table you enter heights above water
contact and corresponding values for water saturation. The system uses
the function to calculate an average saturation in the hydrocarbon filled
portion of the structure.
Water saturation estimates are defined as constants. They can be flexed
using a saturation uncertainty height multiplier.
Height [meters or feet] is the height above the hydrocarbon water contact.
Water saturation [fraction or %] is the amount of interconnected pore
space that is filled with water at the corresponding height above the water
contact. Hydrocarbon saturation is 1 – water saturation.
Saturation uncertainty multiplier [fraction or %] is an uncertainty factor
that is applied to the water saturation estimate.
Note
•
The Saturation uncertainty multiplier can also be edited on the
Petrophysical Parameters tab.
You edit the saturation height table by using the commands below and
then double clicking on the entries. The double click opens a Parameter
Input Panel with a single value for respectively height and water saturation
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July 2013
Alternatively, copy the table from for example a spreadsheet and then
paste into the table using the right-click command “Paste from clipboard”.
Add is to add a new height interval.
Remove is to remove the selected height interval.
Sort is to sort height intervals in ascending order.
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July 2013
About Petrophysical Parameters page
This volume page defines the petrophysical inputs for estimation of
hydrocarbon pore volume when using a depth dependent representation of
GRV and a saturation height table to define water saturation in the
transition zone.
Net/Gross Ratio [fraction or %] is the proportion of the reservoir thickness
made up of sand.
Note
•
When the 2-parameter Net/Gross model is chosen, then the Net/Gross
Ratio is replaced by two parameters: Net sand fraction [fraction or %]
is the fraction of the GRV that is of the desired facies; (net sand) /
(gross interval). Net reservoir fraction [fraction or %] is the fraction
of the desired facies that is of reservoir quality; (net reservoir rock) /
(net sand).
Porosity [fraction or %] is the amount of interconnected void space in the
reservoir rock.
Saturation uncertainty multiplier [fraction or %] is an uncertainty factor
that is applied to the water saturation estimate.
Note
•
The Saturation uncertainty multiplier can also be edited on the
Saturation Height tab.
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July 2013
About Saturation Height Function page
Modeling option where saturation is a function of both height above
hydrocarbon water contact and average porosity. The relationship is
modeled using a Lambda function with constants that are empirical
estimates obtained through curve-fitting from analogs.
The saturation height function uses the average porosity distribution
defined on the Petrophysical parameters tab. Mean and P90 – P10 values
from the distribution are shown in the legend box of the diagram
In addition to the estimates of the lambda function constant parameters,
there are two optional parameters:
Irreducible water saturation [decimal or %] is the level at which water
saturation becomes irreducible. The water saturation is clipped at this
value. If this parameter is not present, then the irreducible water saturation
is assumed to be 0.0.
Irreducible water saturation height [m or feet] is an optional parameter that
defines at what height the water saturation becomes equal to the
irreducible water saturation. The water saturation is equal to the
irreducible water saturation at this height and above.
The formula for the lambda function is
S w = m * exp( − n * Ø ) +
a
+c
height b
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July 2013
Where
Sw [decimal or %] is the water saturation or the percentage of the
interconnected pore space that is filled with water.
Ø [decimal or %] is the average porosity
Height [m or feet] is the height above the hydrocarbon water contact
The variables a, b, c, m and n are constants that are typically estimated
from empirical data in analog wells.
Using the lambda function
The GeoX lambda function consists of three main parts: One part (A)
defines primarily how water saturation varies with height above the water
contact.
PART _ A =
a
height b
A is the core lambda function element where b is the lambda coefficient.
The second part (B) defines the effect of porosity on water saturation.
PART _ B = m * exp( − n * Ø )
As we can see, the value of B is a decreasing function of porosity. The
constant m is used boost B while larger n values attenuate the effect of
porosity (Ø).
The last part, the parameter c, is an adjustment factor to control the overall
range of water saturation values.
You can obtain a “stripped” version of the saturation height function if you
put m = 0 to remove the effect of porosity, put c = 0 for no adjustment, a =
1 for direct application of the lambda function and
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July 2013
About Intermediate Results with Saturation Height
Presents estimates of intermediate results such as rock volumes,
hydrocarbon pore volume and calculated fluid parameters. The
intermediates displayed depend on the charge, volume and fluids models
used.
Average Oil Saturation [decimal or %] is the saturation averaged over the
transition zone above the oil water contact and the remainder of the oil
bearing rock volume in the structure.
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July 2013
Dual Porosity
Single segment implementation of dual porosity makes analysis both faster
and less error prone. Intermediate results indicate matrix and fracture
volumes for immediate verification of results.
The implementation of Dual porosity functionality consists of the division
of the calculation of the Total Net Rock Volume in: Fractured Net Rock
volume and Matrix Net Rock Volume. With the new Dual porosity
capability in GeoX 6 there is possible to split up porosities, saturations,
and recovery factor for matrix and fractured element in the same reservoir
using one segment analysis.
About HC fluids modeling SETUP
Is used to indicate what HC phases are active in the segment analysis. If
your GeoX license also includes the unconventional resource option, this
page alternatively sets up either a shale gas or coal bed methane (CBM)
segment analysis.
The choice of HC phase defines the relevant subset of input parameters
that are active on the Volume and Reservoir Input pages. Together with
the HC fluids modelling set-up and the reservoir set-up, these setups define
the active parameter set in the segment analysis.
The "oil, gas, OR oil and gas" option defines a case where mutually
exclusive alternative HC phase scenarios are active. If the HC phase
risking option is active in the risk model, then you enter the relative
probability of the different phase outcomes on the HC phase risking subpage of the Risk Input page.
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July 2013
Note
•
Use of the HC product scenario requires that the HC phase risking is
checked in your risk model.
The Marketable section defines what products are marketable. The
selection is used to calculate the total marketable resource estimates
presented on the Summary results page.
The “Shale gas” and “Coal bed methane CBM” options define the case
where the segment analysis volume and fluids pages are set up to model
the adsorbed gas component and free gas component for respectively a
shale gas or a coal bed methane (CBM) asset. The volume page supports
solely simple area_and_thickness slab models for GRV.
The check box for Volumes Charged is used to activate estimation of the
volumes of oil or gas that are charged to the segment. When the box is
checked, the system adds a notebook input Charge page.
The check box for Dual porosity is used to activate the estimation of the
volume of oil or gas that are associated to matrix or fractured portion of
the reservoir. When the box is checked, the system adds the option in
volume setup page for splitting the Saturation and Porosity for matrix and
fracture as well as Recovery Factor for Oil and Associated Gas of the two
components respectively.
The check box for Computation of Dry Gas, NGL and Non Sales Gas is
used to extend the estimation model with parameters to compute in-place
and recoverable NGL and dry gas in addition to the percentage of the dry
or natural gas that cannot be sold due to higher levels of inerts, nonhydrocarbon gases, or hydrogen sulphide.
Notes
•
•
•
•
•
Volumes charged can only be checked if the Volume model is setup
for a depth dependent representation (see Setup tab of Volume page).
When Volumes charged is active, the phase scenario alternative (oil,
gas OR oil and gas) is greyed out.
Dual porosity can only be checked with conventional resources
modelling.
When checking on ‘Computation of Dry Gas, NGL and Non Sales Gas
(as opposed to direct estimation of NGL)’, total resources (OE or GE)
is computed from primary and secondary recoverable volumes of oil
and Condensate and recoverable NGL and dry gas.
When checking on ‘Computation of Dry Gas, NGL and Non Sales Gas
(as opposed to direct estimation of NGL)’, direct estimation of NGL in
Tons is removed.
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July 2013
About Volume Setup for Dual porosity
This page is used to set up the options for alternative approaches to
modeling hydrocarbon pore volumes.
When Dual porosity option is activated on the Setup page there is the
possibility to choose if Porosity and Oil Saturation will be common for
matrix and fractured components. If the boxes are unchecked then there
will be different parameters for each component.
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July 2013
About Volume Parameters for Dual porosity
This page defined the main inputs for estimation of the common rock
volumes as well as the fraction of the Net Rock volume that is fractured.
This is defined by the Fraction fracture parameter. In addition if it was
chosen to not share Porosity and Oil saturation for matrix and fracture in
the Setup page, then it is needed the definition of these parameter for each
component of the reservoir, if the selection is share parameter then the user
has to defined one porosity and one Oil saturation that will be used for
both, matrix and fractured.
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July 2013
About Fluid Setup for Dual porosity
This page is used to select among the alternative representations of the
parameters that define HC resources at surface conditions as well as
associated products and the recovery factor model. When Dual porosity
capability is activated in the Setup page is also possible to choose if the
same Recovery Factor for Oil and Associated gas will be used for matrix
and fracture components of the reservoir. For using different Recovery
Factors for each reservoir element then the boxes should not be
highlighted.
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July 2013
About Fluid Input parameters for Dual porosity
The fluid page defines, together with the Volume page, the main inputs for
estimation in-place and recoverable resources at surface conditions. The
active fluids parameters are defined on the Fluid Setup page. If Recovery
Factor for Oil and Associated Gas were chosen as not share parameters
then the user has to define each recovery factor for matrix and fracture
components, otherwise the same recovery factor for each phase will be
used by both elements in the reservoir.
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July 2013
About Intermediate results for Dual porosity
Intermediates results displayed depends on the charge, volume and fluids
models used as wells as what HC products are being modeled. With the
new Dual porosity functionality now it is displayed matrix and fracture
volumes (in-place and recoverables), for immediate verification of results.
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July 2013
New Bayesian Risk Modification Procedure
The existing Bayesian Risk Modification (BRM) procedure for handling
seismic anomalies (DFI’s) has been extended to produce BRM chance
estimates for each risk factor.
About Risk
This page is used to define the estimates of shared play and conditional
segment risk (chance) factors that control the geological success of the
segment. The estimates are entered in a Parameter Input Panel that is
opened by double-clicking on the appropriate cell on the Risk page.
The "DFI is applicable in segment" check box is used to activate DFI risk
modification. The check box is available if your risk model has been
configured with DFI risking.
The “HC phase risking” check box is used to activate HC phase scenarios
where you can model the probabilities of respectively an oil case, a gas
case, or an oil leg and gas cap case.
Note
•
The check box is available if your risk model has been configured with
HC phase risking.
Risk factors are typically defined according to company best practice
standards. You can browse your company custom risk factor definitions in
the Definition pane at the bottom of the Risk page.
Note
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July 2013
•
The default GeoX play risk (chance of adequacy) factors are:
o Trap and Seal [fraction or %] is the probability that the shared
trap area, top-seal and fault seal conditions are sufficient to
contain at least one accumulation in the play with minimum
hydrocarbon volume or more.
o Reservoir Presence [fraction or %] is the probability that the
shared reservoir thickness condition is sufficient to contain at
least one accumulation in the play with minimum hydrocarbon
volume or more.
o Reservoir Quality [fraction or %] is the probability that the
shared reservoir condition is of sufficient quality to allow
recovery of minimum hydrocarbon volumes or more from at
least one accumulation in the play.
o Source and Migration [fraction or %] is the probability that the
shared source richness, maturation, migration and timing
conditions are sufficient to charge at least one accumulation in
the play with the minimum recoverable hydrocarbon volume or
more.
The default GeoX conditional segment risk factors are identical to the
play factors.
Marginal play probability [fraction or %] is the probability that the play is
favorable for one or more hydrocarbon accumulations of minimum size.
This is the chance that all shared geological controls in the play are OK.
Conditional segment probability [fraction or %] is the probability that the
segment is an accumulation, given that the play is favorable for
hydrocarbon accumulations.
Unconditional probability [fraction or %] is the probability that the
segment is an accumulation. This is the fully risked (unconditional)
chance of success.
Dry hole risk [fraction or %] is the probability that the segment is dry.
This is 1 - unconditional segment probability.
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July 2013
About Initial Fluids & Reservoir Probabilities
The Initial Fluid and Reservoir Probabilities is used to enter your estimates
of non-success fluids and lithology conditions.
The system will automatically set up the relevant scenario probabilities
according to the link existing between geological risk factors and DFI risk
category.
Note
•
For use of the DFI functionality, your risk model has to have assigned
each risk factor to one of the following five categories of generic
geological controls:
o
o
o
o
o
Trapping
Reservoir quality
Reservoir presence
Sourcing
HC quality
Overall Hydrocarbon Probabilities
P(Oil) [decimal or %] is the conditional probability of finding oil given
that the segment is a hydrocarbon accumulation.
P(Gas) [decimal or %] is the conditional probability of finding gas given
that the segment is a hydrocarbon accumulation.
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P(Oil & Gas) [decimal or %] is the conditional probability of finding oil
and gas given that the segment is a hydrocarbon accumulation.
Note
•
The Overall Hydrocarbon Probabilities must always sum up to 1.0.
Failure Hydrocarbons Probabilities
P(Failure Oil) [decimal or %] is the conditional probability of finding
failure oil (such as heavy oil) given that the segment is an oil
accumulation.
P(Failure Gas) [decimal or %] is the conditional probability of finding
failure gas given that the segment is a gas accumulation.
P(Failure Oil&Gas) [decimal or %] is the conditional probability of
finding failure oil&gas given that the segment is an oil&gas accumulation.
The probabilities are re-normalized by the software such that the total
failure HC probability matches the geological probability of failure HC,
i.e. P(fail HC) = P(success fluids) * P(eval. Res.) * (1-P(HC quality)).
This implies that if HC quality is not present in the risk model, the failure
HC probabilities will not be used in the computation.
The computations of the different success and failure scenarios are as
follows:
1) P(oil) = P(success oil) + P(failure oil)
2) P(gas) = P(success gas) + P(failure gas)
2) P(oil+gas) = P(success oil+gas) + P(failure oil+gas)
3) P(success HC) = P(success oil) + P(success gas) + P(success oil+gas)
4) P(failure HC) = P(failure oil) + P(failure gas) + P(failure oil+gas)
Other Failure Fluids Probabilities
P(Water) [decimal or %] is the conditional probability of finding water given that
the segment is not a hydrocarbons accumulation.
P(Low Saturation Gas) [decimal or %] is the conditional probability of finding low
saturation gas given that the segment is not a hydrocarbons accumulation.
P(Other) [decimal or percentage] is the conditional probability of finding some
other failure fluid other than water or low saturation gas given that the segment is
not a hydrocarbons accumulation.
Note
•
The Other Failure Fluids Probabilities must always sum to 1.0.
Reservoir and Non Reservoir Probabilities
P(evaluated reservoir) [decimal or %] is the probability that the reservoir is
as evaluated in the volumetrics.
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July 2013
P(non- evaluated reservoir) [decimal or %] is the probability that the
reservoir is there, but is outside the range evaluated in the volumetrics.
P(non-reservoir) [decimal or %] is the probability that the reservoir has a
non-reservoir lithology.
Note
•
If all the risk factors are mapped to the correct risk categories in the
exploration risk model editor, the following is true:
P(Reservoir) + P(Non Reservoir)= 1.0.
P(Evaluated reservoir) = P(reservoir presence) * P(reservoir quality|
reservoir presence).
P(Non-evaluated reservoir) = P(reservoir presence) * (1 - P(reservoir
quality| reservoir presence)).
Non Reservoir Probabilities
P(non-reservoir 1) [decimal or %] is the conditional probability that the
reservoir has a non-reservoir 1 lithology, given that it has a non-reservoir
lithology.
lithoogy.
lithology.
Notes
•
•
The Non Reservoir Probabilities must always sum to 1.0.
The Non Reservoir Probabilities are only relevant if the P(nonreservoir) is different from 0.0.
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About DFI likelihood assessment
The Bayesian Risk Modification procedure is implemented in this page. It
uses the success and failure prior probabilities computed from the
geological risk assessment and the conditional indicators probabilities
(likelihoods) assigned by the user.
The conditional indicators probability (likelihood) estimates can involve
three success cases:
•
•
•
P(Ind| success oil and evaluated reservoir) [fraction or %] is the
conditional probability of occurrence of the observed indicator(s) given
that the segment is a success oil accumulation with the success
(evaluated) reservoir.
P(Ind| success gas and evaluated reservoir) [fraction or %] is the
that the segment is a success gas accumulation with the success
P(Ind| success oil&gas and evaluated reservoir) [fraction or %] is the
that the segment is a success oil&gas accumulation with the success
The conditional indicator probability estimates can involve up to 18 failure
cases:
P(Ind| success oil and non-evaluated reservoir) [fraction or %] is the
that the segment is a success oil accumulation with the failure (nonevaluated) reservoir.
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P(Ind| success gas and non-evaluated reservoir) [fraction or %] is the
that the segment is a success gas accumulation with the failure (nonevaluated) reservoir.
P(Ind| success oil&gas and non-evaluated reservoir) [fraction or %] is the
that the segment is a success oil&gas accumulation with the failure (nonevaluated) reservoir.
P(Ind| failure oil and non-evaluated reservoir) [fraction or %] is the
that the segment is a failure oil accumulation with the failure (nonevaluated) reservoir.
P(Ind| failure gas and non-evaluated reservoir) [fraction or %] is the
that the segment is a failure gas accumulation with the failure (nonevaluated) reservoir.
P(Ind| failure oil&gas and non-evaluated reservoir) [fraction or %] is the
that the segment is a failure oil&gas accumulation with the failure (nonevaluated) reservoir.
P(Ind| failure oil and evaluated reservoir) [fraction or %] is the conditional
probability of occurrence of the observed indicator(s) given that the
segment is a failure oil accumulation with the success (evaluated)
reservoir.
P(Ind| failure gas and evaluated reservoir) [fraction or %] is the
that the segment is a failure gas accumulation with the success (evaluated)
reservoir.
P(Ind| failure oil&gas and evaluated reservoir) [fraction or %] is the
that the segment is a failure oil&gas accumulation with the success
P(Ind| water and evaluated reservoir) [fraction or %] is the conditional
segment is a water accumulation with the success (evaluated) reservoir.
P(Ind| water and non-evaluated reservoir) [fraction or %] is the
that the segment is a water accumulation with the failure (non-evaluated)
reservoir.
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P(Ind| water and non-reservoir 1) [fraction or %] is the conditional
segment is a water accumulation with the failure non-reservoir of type 1.
P(Ind| low saturation gas and non-evaluated reservoir) [fraction or %] is
the conditional probability of occurrence of the observed indicator(s) given
that the segment is a low saturation gas accumulation with the failure (nonevaluated) reservoir.
P(Ind| low saturation gas and evaluated reservoir) [fraction or %] is the
that the segment is a low saturation gas accumulation with the success
P(Ind| other and non-evaluated reservoir) [fraction or %] is the conditional
prospect is a other fluids accumulation with the failure (non-evaluated)
reservoir.
P(Ind| other and evaluated reservoir) [fraction or %] is the conditional
segment is a other fluids accumulation with the success (evaluated)
reservoir.
Notes
•
•
•
The likelihoods of the cases defined with 0.0 probability of
occurrence in the Initial Fluids and Reservoir Probability page will
not be present in the DFI assessment page.
The DFI risking is only available if the DFI risking option has been
selected in the risk model. The DFI option is set using the Risk
Model editor.
The differential between the conditional probability estimates
entered influences how much the DFI affects the DFI adjusted
probability of finding hydrocarbons. If all the conditional
probabilities of the indicator are identical, then there is no
adjustment of the chance of success; if the conditional probability
of the indicator given the success case is much larger than the
conditional probability of the indicator given the failure case, then
there can be a significant upwards adjustment of the chance of
success.
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About DFI Modified risk
Shows the BRM updated play and local (segment given play) probabilities
at the risk factor level.
The overall BRM segment chance of success (unconditional probability) is
the same as the overall success probability shown on the DFI assessment
tab.
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July 2013
Prospect Analysis Tool
Merge of prospect analyses
You can now build rapidly analyses of multiple prospects: You enrol
multiple prospect analyses in a single prospect analysis. Enrol merges the
different prospect analyses with all their dependency, correlation and leak
definitions. The resulting analysis of the “mega” prospect can be edited
with all the functionality of a standard prospect analysis.
The new merge functionality is useful for doing aggregates of prospects in
an area, building analyses of clusters of prospects and for incremental
prospect modelling.
The overall workflow can be defined as follows:
1. Create two or more prospect analyses (e.g. A and B) with their
respective segment, risk dependencies, leak connections
2. Create a new prospect analysis (e.g. C1)
3. Enrol the two prospect analyses (A and B) in C
4. Define additional relationships in C between segments A and B
5. Calc and save C
Note
•
1
The link between the prospect analyses that have been added to a new
prospect analysis is not active. To update the mega prospect analysis
when there are changes in the enrolled prospect analyses requires that
you first remove the enrolled prospect and then re-enrol it.
C can also have its own segments (segment analyses)
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About the segment and prospect analysis selector
The analysis selector is used to select multiple analyses for enrolment in
the prospect analysis.
Analyses are selected by checking the relevant check boxes.
Note
•
Select one analysis per segment folder and prospect folder.
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About Enrolled by play
The “Enrolled by play” tab of the Definition page is used to view the set of
segments (segment analyses – one per segment) enrolled in the prospect
analysis. The segments are organized according to the plays (part-plays)
that they are in.
Add to enroll segments and prospect analyses. Opens a multiple analysis
selector.
Edit opens the selected segment analysis that can then be inspected and
edited.
Remove deletes the selected segment(s).
Note
•
To remove prospects, go to the Enrolled by prospects tab and select the
prospect.
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About Enrolled by prospect
The “Enrolled by prospect” tab of the Definition page is used to view the
set of prospects (prospect analyses) with associated segments (segment
analyses) enrolled in the current prospect analysis. The segments are
organized according to the prospects that they are in.
.
Add to enroll segments and prospect analyses. Opens a multiple analysis
selector.
Edit opens the selected segment analysis that can then be inspected and
edited.
Remove deletes the selected prospect(s) or segment(s).
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About the Risk and Volume dependency group panel
The Risk and Volume dependency group panel is opened on the relevant
risk and/or volume dependency type.
Note
•
The label and number of risk and/or volume dependency types are
defined in your customized risk model. Typical types are reservoir
presence, reservoir quality, trap, seal, source and migration. Check
with your GeoX coordinator for more details.
Name is a short distinctive label for the risk dependency group. It can
often be the attribute or aspect of the prospect that defines the basis for the
grouping of segments in risk dependency groups.
Risk dependency can be defined either via a shared probability for the
segments in the risk dependency group or via Max correlation. The latter
is equivalent to doing nested risk dependency groups for the segments in
the risk dependency group.
P(shared) is the probability of adequacy of the shared geological control
for the risk dependency groups that you have already defined.
Note
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•
Shared probability cannot be lower than the largest conditional
segment probability of the segments in the risk dependency group.
The system automatically constrains the shared probability once you
have checked the segments to be included in the risk dependency
group.
P(segment | play ) is the conditional segment risk given (shared) play risks
for each segment for the dependency group risk factor.
P(conditional ) is the conditional segment risk for the risk factor given the
shared risk
Risk [check box] is used to indicate the segments that are in the risk
dependency group.
Volume [check box] is used to indicate the segments that are in the volume
dependency group. The lower panel indicates the parameters that are
correlated when the segments are included in the volume dependency
group.
Description summary [text] is used to document the basis for the definition
of the members of the risk dependency group and the value of P(shared).
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DFI dependency
A new DFI dependency concept complements the enhanced Bayesian Risk
Modification procedure at the segment level. DFI dependency groups
with associated correlation can be used to model the amount of
information provided by seismic anomalies on multiple segments in a
prospect. Prospect analyses with DFI can now be run with full cycle
analyses and can be aggregated.
About DFI Dependency
This page is used to define possible dependencies among the anomalies
(DFIs) observed in multiple segments. Segments can be grouped in
multiple non-overlapping DFI dependency groups.
Add to add a DFI dependency group. The system opens the DFI
dependency group panel.
Edit is to open the DFI dependency group panel on the selected DFI
dependency group.
Delete is to remove the selected DFI dependency group.
Notes
•
If just two segments are enrolled in a DFI dependency group, the
default (average) and the maximum value coincide.
Page 63
July 2013
•
For details about DFI dependency groups refer to: Martinelli, Langlie
and Stabell, “Handling Seismic Anomalies in Multiple Segment
Prospects - Explicit Modeling of Anomaly Indicator Correlation”,
2013, Proceedings of 75th EAGE conference, DOI: 10.3997/22144609.20130439.
Page 64
July 2013
About the DFI dependency group panel
The DFI dependency group panel is used to define or edit the DFI between
segments in a DFI dependency group. The DFI correlation factor is set to
a value between 0 and a maximum value.
Name is a short distinctive label for the DFI dependency group. It can
often be the attribute or aspect of the prospect that defines the basis for the
grouping of segments in DFI dependency groups.
Default (suggested) DFI correlation value is the average of all the
geological risk dependencies between any two segments enrolled in the
DFI dependency group. The default value can be overwritten by ticking on
the “overwrite default” box.
Overwrite default checkbox is used to indicate that the system should use
a correlation value different from the suggested (default) value. A slide
bar indicates the permissible range: 0 to Maximum value.
Maximum DFI correlation value reflects the maximum geological risk
dependency between any two segments in the DFI dependency group. The
system automatically constrains the DFI correlation parameter once you
have checked the segments to be included in the DFI dependency group.
Risk Checkbox ([ ]) is used to define the segments in the DFI dependency
group
Page 65
July 2013
About Number of segments discovery
Provides an estimate of the number of successful segments across all
success case outcomes.
Page 66
July 2013
Excel report on segments in a Prospect analysis
You can now make an Excel report on a prospect analysis that includes all
properties, inputs and results needed from the enrolled segment analyses.
About Template mappings in Report template editor
Template mappings are used to link analysis variables to an Excel
spreadsheet report. To add a new mapping, use the File menu or right click
in the Template mappings panel.
New mapping is for creating a link between an analysis element (input,
result, attribute or property) and a cell in the spreadsheet template.
Edit mapping is for editing the selected mapping
Delete mapping is for deleting the selected mapping
Copy mapping is for making a copy of the selected mapping
Page 67
July 2013
The New mapping selection has a number of submenus for selection of the
analysis element that is to be mapped.
Add mapping for analysis attribute is used to map general prospect
analysis attributes. Some examples for prospect analysis attributes are:
name, ID, creation date and modification date, GeoX version.
Add mapping for property parameter is used to map prospect
properties. If there are several prospect properties templates, then you
need to first select the appropriate properties template and then the
property to be mapped.
Add mapping for result is used to map multi-element prospects results.
Examples are resource diagrams, joint segment probability table,
dependency groups and play fractionals.
Add mapping for result parameter is used to map prospects total results.
Examples are prospect in-place and recoverable resources, working
interest results, net results, probability summary results.
Enrolled analysis mappings is used to map elements from the enrolled
segment analyses.
Page 68
July 2013
About Enrolled analysis mappings in Template mappings
The “Enrolled analysis mappings” selection is used to map from enrolled
segment analysis variables to the prospect analysis Report template. All
the mappings obtained are reported in a list format, with values for each
selected variable in a separate row.
Add mapping for analysis attribute is used to map general segment
analysis attributes. Some examples are: segment name, ID, creation and
modification date, GeoX version, calculation status, among others.
Add mapping for property parameter is used to map segment
properties.
Add mapping for input parameter is used to map segments inputs
(Volume, Charge and Fluids parameters).
Add mapping for result parameter is used to map segment results such
as in-place and recoverable resources, working interest results, net results.
Add mapping for risk parameter is used to map risk factor estimates.
Page 69
July 2013
Illustrative example of an “enrolled analyses” report
Consider the case where you want to report on the name,
COS (chance of success) and the P90-P50-P10 of the Oil accumulation
size for each segment enrolled in a prospect.
The following reporting template will place the desired data on the
“DataEnrolled” sheet of the Exel spreadsheet.
Selecting the Excel report command with “Test ProspectReport” in a
prospect analysis with 4 segments gives the following report:
Page 70
July 2013
Full Cycle Analysis Tool
Production-only full cycle models
The new “Production only” option supports rapid and simple modelling of
full cycle projects. You do not need to enter cost and fiscal data. The
system limits result estimates to production (profiles and summary
performance indicators). The option is set on the Setup page by
unchecking the “Calculate costs and fiscals” check box.
About Setup
The Setup page is used to set up the number of trials in the simulation and
the initial seed for the series of pseudo-random numbers used to sample
the input distributions. The Setup page defines project parameters such as
discount rate and discount date, and also allows you to run Full Cycle
analysis without cost and fiscal inputs.
Checking the “Use initial seed” check box assures that the simulation will
always start from the same initial seed. Given the same initial seed and the
same inputs, the system will generate the same set of pseudo-random
numbers and therefore also generate the same results.
The project start date controls the reporting of results: results are reported
from the year that corresponds to the project start date.
The net present value date defines the date that cash flows are discounted
to. The net present value calculation ignores cash flows prior to the net
present value date (year).
Discount rate [%] defines the discount rate used to compute net present
values.
Page 71
July 2013
Checking the “Calculate cost and fiscal” check box adds in cost and fiscal
inputs and results.
Page 72
July 2013
Illustrative production only inputs
When the option Calculate with cost and fiscal is un-checked the system
removes Economic scenario and Fiscal regime pages. Further, the
parameters related to cost are hidden and inactivated in all activities on
Activity page.
A production activity when option Calculate with cost and fiscal is unchecked.
When the option Calculate cost and fiscal is checked, the input pages
Economic scenario and Fiscal regime pages are reactivated as well as the
cost related inputs parameters in all activities.
A production activity when option Calculate with cost and fiscal is checked.
Page 73
July 2013
About Results with Production only
When calculating the analysis with the Option Calculate with Cost and
Fiscal unchecked only the Project group results pages will be visible (and
Working Interest). These results pages will remain as before, beside the
CAPEX/HC unit, OPEX/HC unit and Government take on the summary
page will be removed.
Page 74
July 2013
Direct entry production profiles
Need to use production profiles prepared outside of GeoX? Want to make
a field model that does not follow the standard buildup-plateau-decline
format? The new direct entry type well lets you paste in a production
profile package (main and associated products and water).
About the Well type panel (Parameters tab) – Direct Entry
The Parameters tab on the well type panel is used to define the duration
and costs for the injector type well defined in the production activity.
Drilling duration [Yr]: Time it takes to drill the producer
Start production delay [years]: Delay of production after completion of
drilling well.
Unit cost per well [million USD]: Drilling and completion cost per well2.
Operating costs [million USD / Yr]: Operating costs per year for the
well5.
These parameters will not be visible when the option “Calculate cost and
fiscals” is unchecked on the Setup input page of the Full Cycle analysis
The Definition tab on the well definition panel is used to name well type
and save well as a well type template the Templates tab in GeoXplorer.
The name gives a unique identifier for well type that is displayed in Label.
2
These parameters will not be visible when the option “Calculate cost and fiscals” is
unchecked on the Setup input page of the Full Cycle analysis
Page 75
July 2013
Save as Save well type in Well type template folder hierarchy.
See also Well type definition tab and GeoXplorer Templates
Page 76
July 2013
About the Well type panel (Production Profiles) – Direct Entry
The Production Profiles tab allows you to directly enter profiles for the
different HC phases and water to model the well production.
The Table tab displayes the entered profile with rate defined on the Edit
Profiles window (See About Edit Profiles)
Edit Opens the Edit Profiles window where the profiles can be entered or
pasted in.
Page 77
July 2013
About Edit Profiles
The Edit Profiles window allows you to input the production profiles for
the different HC phases and water. The table allows for entry of main
hydrocarbon phase, associated product and water production rate
[Production] for the specified time intervals [Frequency]. .
Frequency [Annual, Monthly or Daily] defines the time resolution of the
profiles.
Production [Per Day or Per frequency period] defines if the value for each
product is the cumumlative for a period or given as average daily
production within the period.
You can either enter the profiles manually or using copy-paste via the
clipboard
Add is used to add a row in the table.
Delete deletes the selected rows in table.
For entry via clip-board, copy the target profiles into the clip-board, rightclick within the table area, and then select “Paste from clipboard”. The
table needs to have four columns (relative year, primary product,
associated product and water) where all entries have values [0, >].
Page 78
July 2013
New folder structure for Full cycle templates
Multiple-level folders provide more effective management of Economic
scenario, Fiscal Regime and Well type templates. You can now define a
more detailed and customizable sub-division of the templates. This opens
for more systematic use of the Approve functionality and improved quality
assurance of your templates library.
The Economic scenarios, Fiscal regimes and Well type templates are
created within a subfolder of the respective directories on the Templates
tab of the GeoXplorer.
About GeoXplorer Templates
There are two types of templates: Templates for analyses and templates
with data that can be used in full cycle analyses.
Analysis templates are used to facilitate and guide the definition of
analyses. There are templates for undrilled segment, discovery segment,
dry segment, well target, play and play area yield analyses. These
templates are presented when you create a new analysis. Typically the
templates reflect your company best practices and preferences.
There are three types of full cycle analysis templates: for economic
scenarios, for fiscal regimes and for well types. These template analyses
can be loaded into your full cycle analysis.
The sub folders for the full cycle analysis templates are created by rightclicking on one of the three template folders.
Page 79
July 2013
Illustrative full cycle template folder structure
Consider the following folder structure for Norwegian fiscal regimes.
Norway is in the Europe folder. Within Norway, the Norwegian regimes
are organized with two additional folder levels: by interest and by ring
fencing. At the lowest level of the folder structure, there is one Approved
and potentially several Historical or Test fiscal regimes.
Page 80
July 2013
Well types templates
The definition of type wells in production activities typically involves
using representative type wells. The new type well template functionality
facilitates managing and sharing type well definitions.
The templates can be either created from a production activity by the
“Save As” option of a Full cycle analysis or directly in the GeoXplorer
Templates tab.
The well types can either be field based production wells, well based
production wells, direct entry wells (for well based production) or injector
wells.
About the Well type Definition tab (Production activity)
The Definition tab on the well definition panel is used to name and
document the Well type in a Field-based or in a Well-based production
activity. The tab is also where you can save the type well in your template
library.
Name is the name of the Well type (max 216 characters).
Description [text] is the text that documents the Well type
Save as.. saves the well type as a template.
Page 81
July 2013
About the Well type Definition tab (direct Template)
The Definition tab for a template Well type defines the main HC phase.
The tab is also used to document the well type template.
Native currency is the currency used when defining related template
inputs (such as unit cost of the well). The currency is changed by selecting
Currency under Edit in menu.
HC type [oil; gas] is the type well main product.
Description [text] is used to documet the type well.
Note
• The name of the type well template is displayed in the header of the
template analysis. The name can be given at the initial save of the
template. The name can be also changed in the well type template
folder in the GeoXplorer.
Page 82
July 2013
About the Well types tab
Producers and injectors are defined on the Well types tab. Producers and
injectors can also be defined by templates that are loaded from the well
type templates library. The producers can either be field- or well- based.
Direct entry producers are always for well-based production activity
models.
The well type panel summarizes the wells defined for the production
activity in terms of the label, usage, operating cost, unit cost and duration
of drilling.
Note
•
Direct entry wells cannot be combined with producers in the same
productivity activity.
Both producers and the injectors have a Definition tab and Parameters tab
in the well type panel, while the well based producer also have a Decline
model tab and Production profile tab. See also About the Well type panel
New: Add a new well type
Copy: Make a copy of the selected well type
Delete: Delete the selected well type
Load: Load a new well type template
Close: Closes the production activity panel.
Page 83
July 2013
About the Well type panel (Parameters tab) – Well based
The Parameters tab on the well type panel is used to define the duration,
costs, peak rates, EUR/ well and decline model for each type well defined
in the production activity.
Drilling duration [Yr]: Time it takes to drill the producer.
drilling well.
well2.
Peak well rate [1000 STB/day]: Peak production rate for well.
Estimated Ultimate Recovery (EUR) per well [million STB]: Estimated
ultimate quantity of either liquids or gas recoverable per well.
Well plateau factor [decimal]: Percentage of production of well where the
well stays at the initial peak (IP) well rate. If well plateau is 0.0 then the
well starts to decline from IP at start of production.
3
Page 84
July 2013
The Definition tab on the well definition panel is used to name the well
type and save well as a well type template the Templates tab in
GeoXplorer. The name gives a unique identifier for the well type that is
displayed in Label.
Save as.. Save well type in Well type template folder hierarchy.
The Decline model tab on the well definition panel for a producer defines
the decline model to be used (Exponential, Hyperbolic, Linear Water Cut,
Logarithmic Water Oil Ratio or Custom) as well as the relevant model
parameters.
See also Decline model tab
The Production profiles tab shows the type well monthly production,
monthly average production rate and monthly cumulative production.
See also Well Resource Diagram tab
Page 85
July 2013
About the Well type panel (Parameters tab) – Field based
The Parameters tab on the well type panel is used to define the duration,
costs and peak rates for each type well defined in the production activity.
Drilling duration [Yr]: Time it takes to drill the producer.
drilling well.
well3.
Peak well rate [1000 STB/day]: Peak production rate for well.
Well plateau factor [decimal]: Percentage of production of well where the
well stays at the initial peak (IP) well rate. If well plateau is 0.0 then the
well starts to decline from IP at start of production.
The name gives an unique identifier for well type that is displayed in
Label.
4
Page 86
July 2013
About the Well type panel (Parameters tab) – Injector
The Parameters tab on the well type panel is used to define the duration
and costs for the injector type well defined in the production activity.
Drilling duration [Yr]: Time it takes to drill the producer
well4.
The name gives an unique identifier for well type that is displayed in
Label.
5
Page 87
July 2013
Creating and Using Well type templates
A well type template can be created within any of the sub-folder(s) below
the Well types folder on the Templates tab in the GeoXplorer.
Right-clicking on one of these sub-folders gives the option to create New
field based producer well type, New well based producer well type or New
injector well type. The system opens the corresponding template.
The well types tabs are defined as for a production activity in the Full
cycle analysis, except that the HC type must be defined on the Definition
tab. The name of the template, in header, is given the first time when
saving the template. See also About Well type Definition tab.
Page 88
July 2013
To re-use well types inputs for other well type templates use Save As
option under File in menu.
The well type templates are loaded from the Well types tab in a production
activity. Selecting Load gives access to the Well type folders with
templates. Select your template and then OK to load template into the
production activity.
To load the well type template into a production activity, the template and
activity must have the same HC product set as main phase. Further, can a
field based production activity only load a field based well type template
and similar, a well based production activity.
Page 89
July 2013
The well type parameters can be edited after Load from Well type
templates as well as copied or deleted within the production activity (See
about Well type.
A new well type template and folder can be created from the Production
activity (See about Well type definition page (Production activity). The
Save as.. option on the Definition tab for a selected Well type enables you
to save this template into a Well type Templates folder(s). You may create
a new folder when using the Save as..option by right-clicking on existing
folders.
Page 90
July 2013
Excel reporting – FullCycle analysis
Make your own custom full cycle analysis reports. The Report template
editor has been extended for support of custom Excel reporting of both
summary data and profiles in full cycle analyses.
The list of report template types is:
Page 91
July 2013
About Template mappings in Report template editor
Template mappings define the link between the full cycle analysis and an
Excel spreadsheet. After having created a new template, add a new
mapping using the File menu or by right-clicking on the Template
mappings panel.
New mapping is for creating a link between a GeoX analysis element
(input, result, attribute or property) and a cell in the spreadsheet template.
Edit mapping is for editing the selected mapping.
Delete mapping is for deleting the selected mapping.
Copy mapping is for making a copy of the selected mapping.
Page 92
July 2013
The New mapping selection has a number of submenus for selection of the
full cycle analysis element that is to be mapped.
Add mapping for analysis attribute is used to map with general
FullCycle analysis attributes. Some examples for FullCycle analysis
attributes are: name, ID, creation date and modification date, GeoX
version.
Add mapping for property parameter is used to map FullCycle
properties. If there are several FullCycle properties templates, then you
need to first select the appropriate properties template and then the
property to be mapped.
Add mapping for result parameter is used to map FullCycle total
results. Examples are contractor results, gross results, working interest
results, PSC results, state participation results, project performance
indicators. Some of the results are distributions, some are profiles.
Page 93
July 2013
Overview of report template mapping alternatives
The full cycle analysis attributes are as for all other analysis types:
Group
Analysis ID
Analysis version
Analysis description
Analysis calculation status
Required sample size
GeoX version
Analysis context
Analysis modified history
Group Variable
N/A
N/A
N/A
N/A
N/A
N/A
Analysis name
Folder name
Play names
Basin names
Analysis folder id
Analysis created date
Analysis created name
Analysis modified date
Analysis modified name
Type
Value
T/A/H
Text
F/T
Value
Label
Label
Label
Column
Column
Value
Date-time
Label
Date-time
Label
Comments
The main distinctive full cycle analysis mapping attributes are for full
cycle analysis results. The following gives an overview of the different
types of results that can be mapped.
Group
Group Variable
NPV
Performance indicators (NPV,
IRR, PI, Total Produced,
EUR/well, CAPEX/BBL etc)
Label
Units
Years
Mean
Mode
Total
Profiles (HC flow, Cash Flow,
Fractiles
NPV, IRR )
Economic scenarios (Oil price, Label
gas price, cost inflation rate) Units
Years
Mean
Sub-Group Level 1
Label
Units
Years
Mean
Mode
Bins
Comments
N/A
N/A
N/A
N/A
N/A
N/A
101 fractiles
Fractile 0
Fractile 1
.....
Fractile 95
Fractile 99
Fractile 100
Type
Label
Units
List
Value
Value
Value
Value
List
List
List
Value
Value
Value
Value
Value
Value
Label
Units
List
Value
Value
Value
List
Value
Value
Value
Value
Value
Value
N/A
N/A
N/A
N/A
Label
Units
List
Value
Same for gas price, condensate price and inflation rate
Fractiles
Sub-Group Level 2
N/A
N/A
N/A
N/A
N/A
Number of bins
Bin width
Bin values
Bin probabilities
101 fractiles
Fractile 0
Fractile 1
.....
Fractile 95
Fractile 99
Fractile 100
Years for the project duration
Mean value by year
Mode value by year
From F0 to F100
Years for the project duration
Mean value by year
The results organize into three different categories: Attributes related to
Summary results (such as NPV, IRR, etc); attributes related to profiles
(such as HC production profiles, cash flow profiles); and attributes related
to economic scenarios (such as oil price, gas price, cost inflation).
Page 94
July 2013
Illustrative Example – Contractor Profile
Consider reporting the mean Contractor Net Cash Flow After Income Tax
profile. This is found under Contractor Results – Net cash flow after
income tax.
To get the corresponding Years, you add in a mapping for Years.
Page 95
July 2013
When you select the Excel report in the full cycle analysis, the system will
show the profile in the report:
Page 96
July 2013
Reserve tracker
Project based classification
Classifications are now 100% project based where by definition all
resources in a project belong to one resource class. RT provides three
inter-related views: Projects, Assets and Entitlements.
Mixed deterministic and stochastic classification
You can now combine stochastic classification and deterministic
classification in one classification model. For example, prospective
resources can use stochastic classes while contingent resources and
reserves can use deterministic classes. Resources are booked on projects
in a project-assets-entitlements framework.
About RT and How to Use RT
RT will be released with GeoX 6.1. The What’s New in GeoX 6.1 will be
devoted to describing in detail how to use the new RT.
Page 97
July 2013
Aslaks vei 14 • N – 0753 OSLO, Norway
Tel: +47- 22 51 07 00
What’s New in GeoX 6
Copyright © 1992 - 2013 GeoKnowledge AS
All Rights Reserved.
No part of this software or documentation may be copied, photocopied,
reproduced, translated, or reduced to any electronic medium or machinereadable form without prior written consent from GeoKnowledge AS.
The information in this document is subject to change without notice and
should therefore not be construed as a commitment by GeoKnowledge
A.S. GeoKnowledge AS assumes no responsibility for any consequences
resulting from errors that may appear in this document.
The software described in this document is furnished under license and
may be used or copied only in accordance with the terms of such license.
Oslo, June 2013
Page 98

What`s New in GeoX 6

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