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# Reservoir Modeling - Science topic

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Questions related to Reservoir Modeling

I am doing a project in the university and I have been asked to do dry hole analysis for some wells in which all data given are seismic and logging data

I am asking if we could use the decline curve analysis (DCA) technique, especially the Arps method to calculate the remaining reserves in the mature phase of production (in case of the presence of multiphase) from petroleum reservoirs or we couldn't rely on it?

Hi guys! I am trying to design a simple two-phase reservoir model (gas-water) using eclipse, and I keep getting the same error message every time, like the picture I attached. Does anyone know what this problem is related? Any suggestions would be appreciated!

I'm trying to build a 3D velocity model (on a previously constructed 3D structural framework) in Petrel Software using only checkshots. Can anyone help me, please?

I would like to use Brugge field dataset for well placement optimization. it is developed by TNO

and I can not find the data in the website.

However, One paper has given the data file as a supplementary in this paper

( ). So my question is can I use this paper's data for my study with acknowledgment.

I have a watershed that has a reservoir (see the picture attached) . I want to model the reservoir as part of my set up. The reservoir takes in water from a stream. Water is withdrawn from the reservoir to feed a power plant.

How can I model the water intake into the reservoir from the stream?

How can I model the water withdrawal of water from the reservoir to the power plant?

Which reservoir modelling method in SWAT should I use?

I am working on optimizing well placement in the condensate reservoir model using an algorithm. Any kind of code example will be appreciated.

The artificial learning hits its performance limits in case of using seismic with low signal to noise ratio to drive the petroleum reservoir modelling. The neural networks tends to learn either from the useful signal part as well as from the noise. What is the best practical way to avoid this problem which can result in a dramatic noise magnification?

I am working on optimizing well placement in the condensate reservoir model using an algorithm. Any kind of code example will be appreciated.

We observed a huge difference between simulated and observed outflows from a catchment during a hydrological modelling exercise in HEC-HMS. The catchment contains numerous ponds and smaller lakes (of varying areal extent), lacking operational data. How can we account for the effect of these storage structures in the hydrological modelling?

What should the payzone thickness be incase of horizontal wells? Should we use MD or TVD?

in terms of Well test interpretation in Kappa Saphir?

I'm just starting to know how to use petrel.

and I was just wondering if it's possible to build an anticline or whatever the complex shaped reservoir model just using "simple grid" in RE(reservoir engineering). (something looks like the attached picture)

All I can model is just a square.

If someone can tell me the brief workflow, it will be a great help

Thanks!

If I want to construct a fracture model in Petrel for a certain area, what are the input data? and what is the general procedure?

Please, I have five (5) reservoir simulation results from five (5) different compositional gradient models. History matching using either of the model will give that model a comparative advantage. How do I know the model that produced the most realistic simulation result? Thank you.

I am performing pore shape analysis and creating pore network models of segmented microCT scans of carbonate plugs.For this purpose I require a parameter to estimate the complexity of a single pore.

In stochastic fracture modelling, is there a specific parameter that refers to how the fractures are well connected (able to percolate)?

If such parameter exist? could we use it through the commercial software fracture modelling package such as Petrel?

Hi everyone!

I'm simulating a 2D oil reservoir in Abaqus, and it's gonna be a "coupled pore fluid diffusion and stress analysis".

I need to use infinite elements on the right boundary of the model, and the rest of the elements are pore fluid/stress.

How can I link between these elements without any warning and error?

Thanks.

Hi, I am trying to perform a transient simulation in CFX of saturated steam injection into an oil reservoir (5-spot injection scheme). Everything works fine when thermal phase change is deactivated. However, when it is turned on, I get error messages from the CFX solver. Below are the details of the simulation:

- Inlet: steam (80%) + water (20%), 500 K

- Reservoir: 100% oil at 310 K at t = 0

- Total time: 24,000h

- Time step: 1h

- Phase model: thermal phase change with sat. temperature as a function of pressure

- Fluid properties: the dynamic viscosity of the fluids is a function of temperature

I have read through the CFX tutorials, tried to decreased the time step, set the saturation temperature and the dynamic viscosity of the fluids as constants, even so, I've been getting those error messages in the 10th time step or so in the CFX solver.

Again, everything works fine when the thermal phase change is off. Am I missing something? Does anyone have any idea on how I should proceed? Thanks.

A typical flow simulator handles around 10

^{5}to 10^{6}cells, while a GM typically contains around 10^{7}to 10^{8}cells. As an essential component of a reservoir management, we have to evaluate the risk and uncertainty of the model responses, and thus we need to run thousands of such simulations [5,6]. Therefore, it is necessary to upscale the properties of the GM grid blocks to a coarsened grid that can be used in a reservoir simulation with an economical amount of computation time, while ensuring that the predictions resulting from the coarse model is close enough to the reference fine-scale model.Upscaling is carried out for the simulation of a reservoir with a single-phase or multi-phase flow. Single-phase upscaling is concerned with upscaling absolute permeability, while multi-phase upscaling deals with upscaling absolute and relative permeabilities.

Tar may feel comfortably fine in crude oil in the reservoir, but may drop out during surface. Tar observed in the lab may not be tar downhole. What is the bets way to characterize tar in the reservoir for reservoir modeling and development purposes?

when Net to Gross ratio (NTG) decrease in the reservoir model, it means that the amount of clay increase?

does anyone has any idea about how NTG effect on the low salinity waterflooding?

Thanks

Hi all,

Greetings. I am modelling a catchment using Arcswat 2012 with many floodplains which i consider as reservoirs in the model. I have calculated all characteristics of reservoirs (floodplains) and the simulated discharge seems fine as the reservoirs clearly have an influence on the peak discharges. However when i look at the output file i noticed the following:

TILE FROM IMPOUNDED WATER = 0.000 (MM)

EVAPORATION FROM IMPOUNDED WATER = 0.000 (MM)

SEEPAGE INTO SOIL FROM IMPOUNDED WATER = 0.000 (MM)

OVERFLOW FROM IMPOUNDED WATER = 0.000 (MM)

When I increase the hydraulic conductivity to 1mm/hr, it give the same output as above.

Could someone explain to me where i have gone wrong? I am using Arcswat2012 (version ArcSWAT 2012.10.2.17).

Elias

Good evening

I would to ask you these questions that will help me in my literature search. 1- does the push-sediment influences the crack propagation in the dam? Because I've noticed that many researchers do not take into account this setting. 2- does the water quality of dam reservoir influence the crack propagation ? 3 What is the best method to model the crack propagation in the body gravity dams taking into account the water pressure; XFEM (Extended Finite Element Method) or DEM (Disrecte Element Method)?

Thank you Best regards

Is it possible for me to use 1D2D hydrodynamic model for generating river reservoir or dam to study the flood impact on studied area before and after built reservoir or dam?

the regional empirical factor will help me to estimate TOC in shale reservoir

What is the petroleum system of the Santos Basin, Brazil?

Dear all,

I only have observed water stage of the reservoir on daily, no observed inflow to reservoir, no observed outflow from reservoir.

I would like to calibrate water stage for a reservoir in SWAT. So how can I do that?

I am looking forward to hearing from all of you soon!

Thank you so much!

Liem

Prior to fit the experimental design model by multiple linear regression, how to validate the model in terms of number of observations, orthogonality , and distance? How to evaluate the last two terms?

i have problem in running regression of PVT analysis. Can anyone explain to me what is the meaning or mathematics theory of changing component-based regression variables (i see some numbers like 1,2 or 3 when we change the variables) and show me the way to do that. Sorry im new in this sector. Thanks a lot.

What is the rational behind refining the grids that has CO2 injection wells n compositional reservoir modeling? Does it affect or facilitate the history matching?

Overall, is it so necessary to implement grid refinery at this problem?

I am trying to design a small reservoir model and looking for a (vacuum?) pump that keeps well bore pressure lower than reservoir pressure.

I prefer a pump that keeps pressure constant, but it doesn't have to be as long as it is not very strong.

I already tried electric vacuum pump but it was too strong.

I also tried hand pump but it was impossible to keep the pressure constant.

Any recommandation?

I am aware that the process itself depends on the geology of the reservoirs to a certain extent in addition to of course development scheme (depletion followed by water injection or gas injection .. etc). I am in the process of trying to compile a benchmarking of recovery vs. reservoir geology vs. mobility ratio vs. heterogeneity (areal and vertical) for different waterflood patters. Then I might try to develop further to other development schemes (gas injection, EOR .. etc)

I am sure that I need to use average drainage radius/permeability, communication between layers and BHP. However this is making it very complicated.

Any ideas? Any suggested references? Any one who is interested in trying this as a first method of field development appraisal/bidding process?

What I am thinking is once these factors are estimated, a reasonable estimate of recovery factor can be achieved even before simulation process starts. Since static and dynamic models are using basically this data to generate forecasts in the first place. Appreciate you feedback and discussion.

It is a routine approach that production logging tool (PLT) data are used to match and find the best correlations for well flowing model in oil&gas fields.

My question is to understand whether it's possible to use a reservoir simulator as data generator for well flow modeling. If this is feasible, the expensive, time-consuming PLT test can be simulated to select the best model for a given reservoir

Hello

i m doing a problem on dam reservoir foundation interaction to apply a unit harmonic ground excitation.. please any body can share how to apply unit harmonic ground excitation on the abaqus model.

It is around two years that Iran's ministry of water and energy is looking for a remediation to salty Gotvand dam. The dam reservoir is placed on geological formation known as "Gachsaran". This formation is completely repleted by structures out of salt, which has changed the quality of water inside the reservoir. This dam is placed in Karoon basin beside Karkhe basin located in the center and south-western of the country. A schematic figure of reservoirs and the drainage system is attached to questions . Any help and notion is appreciated.

I am solving the IMPES equation for the reservoir simulation. I wanted to know the criteria for stability of the equation.

Reservoir modeling for saline aquifers is well accomplished by Generalized Equation of state Modeling software (GEM). I wish to know which model are they choosing for the same viz., Peng Robinson state or Soave Redlich equation or any other model.

distance, discharge from upper reservoir, storage in both reservoir, effects on downstream of lower dam.

Reliability for reservoir operation is defined as number of periods that downstream demand is met to all periods. This definition is applicable for single reservoir system. As multireservoir system may work at series or parallel, I want to know : Is there any "reliability index" to evaluate the operation of multireservoir system ?

In the classical reservoir engineering context, the well drainage radius is normally kept constant; while new findings indicate that it should not be kept constant; rather, the well drainage radius can be subject to change with time, depending on some operating and reservoir parameters.

I am looking for method(s) and techniques to detect and record changes in drainage radius as the well is put into production

How do you determine equilibrium displacement in an injection and production well pattern? Please can anyone give me a clear way of approach or any method to go about it.

In a well pattern say 5 point or 7 point under different reservoir properties arrangement. How do you get equal oil displacement in all the production wells.

With reservoir quality modeling, we can simulate many quality variables in the reservoir such as temperature, salt, alkalinity etc.

Well known 1D simulators, such as HEC5Q, needs MSDOS to run, I want to find a Windows based one for my modeling.

Based on the 3D structure information of a building I want to perform a fluid flow simulation. In particular, I want to find out places with the highest fluid flow density. You can imagine it as filling a building uniformly with water and then finding out where water has the highest flow density. I am looking for a simple-to-use and easy tool to perform this simulation as I am not an expert in the field.

I am interested in this kind of work, and a major part of my master thesis deals with gestatistics and reservoir simulation

Can someone point me to a key publication or review paper that discusses the van Genuchten and Brooks Corey models re: capillary pressure curves. I need to make sure I reference this properly and am having problems finding an appropriate paper aimed and oil and gas reservoirs. Thanks