Carbone is a highly interactive package designed to build, tune and operate on EoS or Black Oil fluid models. Whilst the simplest use case may be to build a PVT model for KAPPA-Workstation or any other Black Oil or Compositional modeling platform, Carbone is designed to be used for more advanced applications in reservoir, production and flow assurance domains. These include constructing a field or asset scale unified EoS model, wax, asphaltene and hydrate studies, compositional gradient calculations, fluid separation and mixing, miscibility pressure calculations and simple process system modeling and optimization.

With speed and ease of use at its core, processes such as fluid and lab data QC, phase envelope generation, flash results and model comparison are automatically performed for any fluid.

Carbone is powered by the technical kernel from IFPEN as part of our ongoing technical partnership.

Built as part of KAPPA Generation 6, Carbone has a web UI and separate back end, allowing various deployment configurations, namely stand-alone, client-server, or through the KAPPA-Automate platform as a microservice.

Carbone offers a multilingual UI, currently supporting English, French, Russian, Chinese and Spanish.

Fluid Definition

Carbone offers an extensive, customizable and extendable internal database of pure and pseudo components to define a fluid.

Twu/Edmister, Lee-Kesler Extended, Riazi/Edmister and Pedersen correlations are available to compute pseudo component properties from Mw, S.G and/or Tb.

In addition to selecting components and defining the composition and properties of a fluid in Carbone, fluids may also be initialized by importing files in Eclipse™ compositional format.

EoS models

Carbone offers the following EoS models:

1. Peng-Robinson, 1978

2. Soave-Redlich-Kwong, 1972

Pseudo component acentric factors and volume shifts may be constrained to component boiling points and component surface densities respectively.

Note: There are additional EoS models implemented in Carbone, but their usage is restricted to specific fluid types only. These include:

3. Abdoul-Rauzy-Peneloux (ARP), 1991: Asphaltenes only

4. Cubic Plus Association (CPA): Fluid phase in Hydrates

5. Søreide-Whitson, 1992: 3-phase aqueous flash calculations

Viscosity model

The following viscosity models are available:

1. Lohrenz-Bray-Clark, 1964 (LBC)

2. LBC Heavy Oil

3. Little & Kennedy, 1968

4. Pedersen, 1987 (Corresponding State Principle, CSP)

5. Ducoulombier, 1986 (adjustement to Pedersen's CSP model for heavy oils)

Critical volumes may be constrained to the Orrick & Erbar, 1973 correlation when using the LBC correlation.

Phase Envelope & Flash Results

A PT phase envelope is simulated on the fly for any fluid. Multiple phase envelopes can be compared.

2-phase Vapor-Liquid (VL) Flash results, including mixture properties, oil and gas phase composition, thermodynamic, transport and thermal properties are automatically computed and output at reservoir and standard conditions. Users can also specify additional pressures and temperatures at which to compute flash results.

For Wax fluids, 3-phase Vapor-Liquid-Solid flash is performed and the output includes solid (wax) phase properties as well.

3-phase Aqueous Flash

The Søreide & Whitson, 1992 model is used for 3-phase aqueous flash. This model is based on the Peng-Robinsion EoS, with the following modifications to improve predictions in the presence of water:

1. Using a modified α-term in the EOS constant a for the brine component as a function of water reduced temperature and brine salinity.

2. Using two sets of BIPs for each binary including water/ brine kijAQ and kijNA for the aqueous phase and non-aqueous phase, respectively. kijAQ is expressed as a function of NaCl brine salinity, hydrocarbon acentric factor and reduced temperature. For kijNA a constant value is applied, except for H2S.


A detailed, multi-sample, field-wide characterization can be carried out in Carbone. The process steps include:

1. Molar Distribution Models: Choose between Exponential or Gamma distribution models and tune model parameters to match a single or multiple samples

2. Characterization Factors: Correlate molecular weight and specific gravity of one or multiple samples from a field using Watson, Jacoby or Søreide Characterization Factors.

3. Boiling Point Estimation: Correlate pseudo-component molecular weight and boiling points using Twu or Søreide correlation.

The tuned characterization can help QC any bad quality GC data and systematically replace bad quality GC data with reliable estimates from the model. In the absence of extended GC data, the plus fraction can also be split into heavier fractions from the characterization.

Once a characterzation is created, it can be applied to any compatible fluid, allowing users to develop field-wide EOS models.

Characterization/EoS Model QC

Carbone offers a wide range of options to QC a given fluid at any stage in the workflow. They fall in to two categories: Category 1 QCs raise warnings; Category 2 QCs rely on different plots which are readily available to the user to view. However, no warning is issued, and the user must manually consult these plots to verify model consistency. All QCs are automatically and always performed on all fluids in a document.

These methods are listed below ((W) for Category 1 QCs, which raise warnings):

1. Fluid phase at Reference Temperature.

2. Phase change during regression (W).

3. Potential OBM contamination (W).

4. Psat > Pref (W).

5. Non-monotonic pseudo-component Pc, Tc or Vc (W).

6. Pseudo-component Tb outside Katz-Firoozabadi SCN range (W).

7. Component property vs. Mw plots.

8. Equilibrium Ratio vs. Pressure and vs. Tb plots.

9. Comparison with lab data: No particular warning is issued, but the errors automatically (and always) calculated and color-coded: Green if difference < 5%, Orange if difference between 5 - 10% and Red if difference > 10%.


Carbone offers three Split options :

1. Standard split: Split the plus fraction to C80 (Conventional oil & gas condensate) or C200 (Heavy oil) assuming an exponential distribution (Pedersen et al., 1983 and 1984) and lump back to a user-defined number of components, based on equal mass lumping method of Pedersen, 1984.

2. Split to Cn+: Similar to (1), except that the split is done to a user-defined Carbon Number (CN). No lumping is done after the split.

3. 'Automatic Wax': This is an automatic split scheme, used to recharacterize an existing fluid for Wax modeling. All fractions between two user-defined CNs are split into Paraffin (P), Naphthene (N) and Aromatic (A) families, based on the method proposed by Nes & Westerns, 1951. Users can specify which of the three families will form part of the solid (wax) phase.


Lumping is used to reduce the number of components of a given fluid. The following lumping methods are available:

1. User defined: groups of components are created by the user. Carbone computes the equivalent properties of these components and assigns them to the groups.

2. Montel Gouel: a target number of components is specified by the user. Carbone automatically groups and computes the components using the method proposed by Montel and Gouel, 1984.

3. SARA: This is an automatic lumping scheme, derived from the method proposed by Scewczyk et al., 1999, to recharacterize an existing fluid for Asphaltene modeling using SARA information.

Fluid Definition

Carbone provides an automatic PNA split scheme based on the method proposed by Nes & Westerns, 1951. Each Single Carbon Number (SCN) between two user-defined CNs is split into Paraffin (P), Naphthene (N) and Aromatic (A) families. Users can specify which of the three component families will be part of the solid phase.

Alternatively, if a fluid is already characterized into solid and non-solid forming components, the component precipitation type can be set when loading this definition.

Precipitation model

The wax model in Carbone is derived from the one proposed by Pedersen, 1995 and is based on the thermodynamic equilibrium between the liquid and solid (wax) phases. The solid phase is assumed to behave ideally. All constituents of a pseudo-component do not necessarily enter into the wax phase. The solid-liquid equilibrium ratio, KiSL, is zero for the non-wax-forming parts of all pseudo-components.

WAT and Wax Precipitation curves are automatically generated for any ‘Wax’ fluid.

Wax Viscosity

Carbone allows input of apparent liquid viscosity (ηapparent) vs. shear rate data and computes fraction of crystallized wax (ɸwax) vs. shear rate using the formulation presented by Pedersen and Rønningsen (2000). Plots of both ηapparent and ɸwax are displayed vs. shear rate.

Model Tuning

A dedicated ‘Wax’ regression is available for ‘Wax’ fluids, allowing users to regress on Melting Point and Enthalpy of Fusion of the Wax forming components to match WAT, Wax precipitation and/or wax viscosity data.

Note: other regression types can also be used for a Wax fluid.

Fluid Definition

Carbone provides an automatic lumping process, which lumps any fluid into a 10-component ‘Asphaltene’ fluid, based on SARA input. The method is derived from Scewczyk et al., 1999.

Following an internal study at IFPEN, the model was further tuned to speed up the Asphaltene calculation process.

Alternatively, if a fluid is already characterized into Asphaltene and non-Asphaltene fractions, component precipitation type can be set when loading this definition.

Risk Assessment

Two methods are available in Carbone:

1. De Boer's method (De Boer et al., 1995)

2. Colloidal Instability Index (CII) method (Yen et al., 2001)

3. Stankiewicz Asphaltene Stability Index (ASI) method (Stankiewicz et al., 2002)

Precipitation Model

The Asphaltene model in Carbone treats Asphaltene as a solubility class and models asphaltene precipitation as Liquid-Liquid demixing. All the constituents are assumed present in all phases and flocculation is considered as the appearance of a second liquid phase.

Abdoul et al., 1991 equation of state is used to analyze the various phases. The entire asphaltene phase envelope for the complete PT spectrum is automatically generated. Additionally, Asphaltene solubility, Asphaltene precipitation, oil density and solid density curves are automatically generated for any ‘Asphaltene’ fluid.

Model Tuning

A dedicated ‘Asphaltene’ regression is available for ‘Aphaltene’ fluids, allowing users to regress on Tc and Mw of the Asphaltene components to match the asphaltene onset pressure and/or precipitation data.

Note: other regression types can also be used for an Asphaltene fluid.

Fluid definition

Hydrate structures of type S1 and S2 can be defined. Impact of the following additives on hydrate phase envelope can be modeled:

1. Methanol

2. Ethanol

3. MEG

For a given setup and additive amount, crystallization temperature at a given pressure (and vice versa) can be calculated.

In addition, Hydrate composition and stability graph with and without the additive is also output. Different inhibitor types and concentrations can thus be studied.

Hydrate model

The hydrate phase is modeled based on the approach proposed by van der Waals and Platteeuw, 1959 and extended by Parrish and Prausnitz, 1972. The fluid phase is modeled using the Cubic Plus Association (CPA) Equation of State.

Conventional Experiments

The following experiments can be loaded and simulated:

1. Constant Composition Expansion (CCE)

2. Constant Volume Depletion (CVD)

3. Saturation Pressure

4. Saturation Temperature

5. Differential Liberation

6. Classical Separator

7. Swelling

Data can be easily pasted from clipboard.

In addition to fluid properties, Carbone also allows users to enter oil and/or gas compositions at each pressure step in the experiment.

These compositions may then be included in the objective function to use in regression.

Precipitation Experiments

The following experiments related to solid precipitation can be loaded and simulated:

1. Asphaltene Onset Pressure (AOP)

2. Asphaltene Precipitation

3. Wax Appearance Temperature (WAT)

4. Wax Precipitation

5. Wax Viscosity

Data can be easily pasted from clipboard.

Sample/Lab Data QC

The following QC methods are available for sample composition and the different lab experiments:

1. Auto-screening of sample composition for OBM contamination

2. Oil density mass balance

3. Composition forward material balance / Bashbush plot

4. Composition backward material balance

5. Z-Factor comparison with Standing & Katz chart

6. Y-Function plot for CCE, DLE and CVD experiments

7. Hoffman plot

Additionally, users can compare different experiments for a given fluid or across multiple fluids within a Carbone document. When comparing experiments, relevant QCs are also compared.

Regression Types & Variables

Nine kinds of regression types are available:

1. Classical pseudo regresses on the following pseudo component properties: Tc, Pc, ω/Tb, Volume Correction/Specific gravity and Kijs.

2. Primary Variables on pseudo component Tb and Specific Gravity, with automatic recomputation of all derived properties.

3. EoS parameters on Ωa and Ωb parameters.

4. Viscosity Model on Critical Volumes and Modified LBC parameters.

5. Automatic Heavy, on the boiling point of the heaviest fraction to match on the liquid density at standard conditions.

6. Mw+, on molecular weight of pseudo-components.

7. Recombination, on flash gas-oil recombination ratio.

8. Asphaltene, on Tc and Molecular weight of Asphlatene fractions.

9. Wax, on Melting Point and Enthalpy of Fusion of Wax fractions.

Two gradient based solvers are available for regression: KAPPA and Hubopt.

Regression Targets

Any lab data associated to a given fluid may be used as regression targets. The granularity of target selection is down to individual measurements points.

Relative weights can be assigned to entire experiments or part of an experiment to customize the objective function.

If compositions have been loaded for different depletion experiments, they can be also included in the objective function for regression

Multi-sample Lab Data Management

Flexible lab data management allows users to compare different experiments for a single sample or across multiple samples loaded in a given Carbone document. Among other things, this facilitates users to:

1. Identify data trends

2. Identify outliers

3. Identify potential groupings

which allows users to gain better insights in to the different data available and aid in the QC of lab data at a field or asset level.

When comparing experiments, any relevant QCs are also compared:

Multi-sample Fluid Management

Flexible fluid management allows users to compare and visualize information contained across multiple samples in a given Carbone document. These include:

1. Sample compositions

2. Component properties

3. Component equilibrium ratios

4. Phase envelopes

5. Flash results at reference or user defined conditions

which allows users to gain better insights in to the different samples at a field or asset level.

Unified Multi-fluid Characterization

Part of the unified EoS development workflow is to use all (or a subset of) available compositions and surface oil density data to arrive at a single characterization for all samples in a given field or asset.

The characterization workflow (detailed under 'Characterization' above) can be easily scaled to multiple samples to achieve this using only a few clicks.

Unified Multi-Fluid Regression

Once a common characterization is built for multiple fluids, a global regression can be run on them. Each fluid will use its composition to match its lab data, while maintaining a unique characterization across all the fluids.

The regression options (detailed under 'Regression' above) can be easily scaled to multiple samples to achieve this using only a few clicks.

Constrained Split and Lumping

Once a common characterization is built for multiple fluids, the same split or lumping can be applied to all of them by enabling the 'Constrained split' or 'Constrained lumping' option in the respective dialogs.

Fluid Definition

Fluids properties can be defined using a broad range of Black Oil correlations (see Technical References). These correlations can also be tuned to user data.

Alternatively, properties may be defined from user tables.

A Black Oil fluid may also be initialized from either KAPPA or Eclipse™ BO files.

Fluid Types

The following Black Oil fluid types can be created:

1. Dry Gas (Hydrocarbon, Pure N2 or Pure CO2)

2. Wet Gas

3. Condensate

4. Dead Oil

5. Saturated Oil

6. Volatile Oil

Water can be included with any of the fluid type.

Flash Results

Flash results, including mixture properties, oil and gas phase thermodynamic and transport properties are automatically computed and output at reservoir conditions. Users can also specify additional pressures and temperatures at which to compute flash results.

A P-x phase envelope is simulated on the fly for Modified Black Oil formulation (Condensate and Volatile Oil Fluid Types).

Multiple phase envelopes can be compared.


For samples which may have been contaminated by Oil Based Mud (OBM), two methods are available to ‘clean’ the sample composition:

1. Skimming: Assumes an exponential molar distribution model for the uncontaminated fluid; used when the mud composition and contamination are not known.

2. Subtraction: used when the mud composition and contamination are known.

An automatic screening is performed on the sample composition to check for possible contamination. If suspected, a warning is issued to the user:


A separation process is a PT flash at a given pressure and temperature. The inputs to this flash are the feed composition, pressure and temperature.

The output of a separation process is two fluids: separation gas and separation oil. Multiple separators can be connected to either stream to design a separator train.

Fluid Mixing

Two fluid streams may be mixed together based on:

1. Target GOR

2. Mole Fractions

3. Volume Fractions at a given P, T

Miscibility Pressure

Minimum and First Contact Miscbility Pressure (MMP/FCMP) may be calculated between an original and an injection fluid. The injection fluid may be single or multi-component.

The calculations in Carbone are based on Neau et. al., 1996. The main benefit of this approach is that MMP is directly computed, without successively simulating Vaporizing and Condensing Drive Mechanisms.

Wellstream Composition Calculation/Adjustment

Producing wellstream compositions can change over time. The wellstream compositional adjustment option can calculate an updated composition (from the seed composition) to match measured GOR.

These calculations are part of the Shrinkage calculations.

Shrinkage Calculation

In the absence of direct stock-tank measurements, the shrinkage option can be used to reliably convert oil rates, measured at test/line conditions to standard conditions.

There are two main inputs to these calculations:

1. Device information: Pressure, Temperature and measured Oil and Gas rates

2. Separator information: Pressure and Temperature of different separator stages in the production/processing facility

The results of these calculations are:

1. Well stream composition, honoring device production ratios

2. Fluid composition at each separation stage

3. Oil and gas rates and properties at each separation stage

4. Shrinkage value

Separator Parameters Optimization

An extension to the shrinkage calculation option, this option allows separator pressure and temperature optimization to minimize shrinkage (maximize liquid yield) over a given number of separtor steps.

Compositional Gradient

The compositional gradient process calculates the variations in composition and properties of a reservoir fluid as a function of reservoir depth. The method in Carbone is based on Montel & Gouel, 1985.

For any depth, compositions can be output as a new ‘Fluid’ on which any process may be applied.

Experiment Design

The Experiment Design tool allows users to generate experimental data for any compositional fluid.

Export Compositional Fluid

Carbone offers the following compositional formats to export fluid PVT:

1. XML compositional (for KAPPA applications)

2. Eclipse™ compositional

3. PROSPER™ compositional

4. CMG compositional (GEM™)

5. OLGA: EoS CTM, EoS TAB and Wax Table

Generate Black Oil Tables

Black oil tables can be generated for a compositional fluid and exported in one of the following formats:


2. Eclipse™ BO and GI


BO properties are generated using the method of Whitson and Torp, 1983. Reservoir depletion processes can be modeled using CCE, CVD or DLE. Surface separator systems can be defined for the export.

Black Oil Fluid

Properties for black oil fluids may be exported in tabular format.

Additionally, an XML output of the black oil fluid setup can be created for easy transfer to other KAPPA modules.

Workflow Integration

Compositional or Black Oil PVT can be exchanged with any KAPPA-Workstation module through a simple Drag and Drop via the KAPPA-Workstation browser.

Additionally, a Carbone document stores all the objects and results of a given session in a human readable JSON structure. This facilitates users to write their own scripts to access any data in a given Carbone document and integrate it within their workflows.