Flow Assurance Technical Section

Good day,

We have recently commissioned a new gas processing plant which is fed thru the Sandstone reservoir. Gas stream contains more than 45% CO2, while water samples are showing presence of Barrium & Strontium.

For early tracebility & to avoid scale deposition in the wellbore, knowledge of P/T which triggers deposition will be helpful. 

The question is, is there any option to model scaling to know triggering conditions? What sort of tests (in addition to 10-ion analysis) shall help and be undertaken?

Regards,
Sahir Inam 

Sahir, as I understand your question, I have few points to add.
This can be achieved by conducting laboratory experiments to determine the solubility of the mineral scale in different pressure and temperature conditions. The results of these experiments can then be used to develop a scaling prediction model that can be applied to field conditions to determine the conditions under which mineral deposition may occur.

Additionally, regular monitoring of wellbore conditions, flow rates, and water chemistry can help to detect early signs of scaling and allow for preventative measures to be taken before it becomes a major issue.

Overall, having a thorough understanding of the pressure and temperature conditions that lead to mineral scaling can help to prevent costly production losses and damage to equipment, leading to more efficient and sustainable oil and gas operations.

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Amjad Saeed Yazdanie
Consultant Business upstream
AVANT Gulf Consulting WLL
Engineering & Energy

Yazdanie@avantengineering.com
18324178656
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Thank you sir.

Original Message:
Sent: 04-11-2023 12:06 AM
From: Amjad Yazdanie
Subject: Scale Modelling

Sahir, as I understand your question, I have few points to add.
This can be achieved by conducting laboratory experiments to determine the solubility of the mineral scale in different pressure and temperature conditions. The results of these experiments can then be used to develop a scaling prediction model that can be applied to field conditions to determine the conditions under which mineral deposition may occur.

Additionally, regular monitoring of wellbore conditions, flow rates, and water chemistry can help to detect early signs of scaling and allow for preventative measures to be taken before it becomes a major issue.

Overall, having a thorough understanding of the pressure and temperature conditions that lead to mineral scaling can help to prevent costly production losses and damage to equipment, leading to more efficient and sustainable oil and gas operations.

------------------------------
Amjad Saeed Yazdanie
Consultant Business upstream
AVANT Gulf Consulting WLL
Engineering & Energy

Yazdanie@avantengineering.com
18324178656
------------------------------

Sahir, the well stream contains water and also  showing presence of Barium & Strontium. Moreover, the gas stream has very high percentage of Carbon Dioxide which is also high source of scaling as well as corrosion inside the top of the tubing. 

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Amjad Saeed Yazdanie
AVANT Engineering & Energy
Consultant Business upstream
Yazdanie@avantengineering.com
18324178656
------------------------------

Sahir, this is the same well which Harris Qureshi of your company has mentioned 3-4 days back here regarding WHSIP is lower than the WHFP 

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Amjad Saeed Yazdanie
Consultant Business upstream
AVANT Gulf Consulting WLL
Engineering & Energy

Yazdanie@avantengineering.com
18324178656
------------------------------

Original Message:
Sent: 04-11-2023 12:17 AM
From: Amjad Yazdanie
Subject: Scale Modelling

Sahir, the well stream contains water and also  showing presence of Barium & Strontium. Moreover, the gas stream has very high percentage of Carbon Dioxide which is also high source of scaling as well as corrosion inside the top of the tubing. 

------------------------------
Amjad Saeed Yazdanie
AVANT Engineering & Energy
Consultant Business upstream
Yazdanie@avantengineering.com
18324178656
------------------------------

Sahir,  Scale prediction software exists such as Scalesoft Pitzer, Multiscale, Scalechem which allow prediction of the type, amount and location of inorganic scale formation based on input pressure/temperature, water and hydrocarbon composition/rates.  The quality of the input data very much impacts the accuracy of the predictions (full ion analysis and organic acid composition within the produced water) but this approach is commonly used to assess the risk of inorganic scale formation.  It is also important to understand the current water you are producing as it may be condensed water or diluted formation water (with condensed water) and an understanding of how that water composition may change with time is important to understand the potential scale risk during the life of your project.
Regards Myles Jordan

Thank you Jordan.

Original Message:
Sent: 04-11-2023 01:42 AM
From: Myles Jordan
Subject: Scale Modelling

Sahir,  Scale prediction software exists such as Scalesoft Pitzer, Multiscale, Scalechem which allow prediction of the type, amount and location of inorganic scale formation based on input pressure/temperature, water and hydrocarbon composition/rates.  The quality of the input data very much impacts the accuracy of the predictions (full ion analysis and organic acid composition within the produced water) but this approach is commonly used to assess the risk of inorganic scale formation.  It is also important to understand the current water you are producing as it may be condensed water or diluted formation water (with condensed water) and an understanding of how that water composition may change with time is important to understand the potential scale risk during the life of your project.
Regards Myles Jordan

Prof. Myles Jordan

Director Marketing, Oil Field Chemicals

ChampionX 

W.SAM WHITE BUILDING, PETERSEAT DRIVE, ALTENS, ABERDEEN, AB12 3HT

E mmjordan@championx.com

Dear Sahir,
there are different software packages that allow modelling scaling process precipitation in production facilities. In our company we adopted OLIStudio by OLI that has a very sophisticated thermodinamic engine able to model any kind of multiphase fluids also in very high conditions of p,T.
For waht concerns input to the model, of course you need accurate of fluids composition, like water characterization (pH, alcalinity , anions, cations, conductivity, TDS etc.) but also very precise composition of the gas to be treated , and be careful with matching corect saturation of gas with water vapor content, to be able to catch the right phase balance during the production process.
Presence of Barium and STrontium is very important to take under control as deposits of this species (usually they combine with sulphates) is very difficult to get rid of as solubility in standard acids is very poor. Most of the times you will need specific scale inhibitors to prevent any deposition along the circuit of your facilities.

Hope this helps.

Kind regards

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ErnestoPetteruti
CHIMEC S.p.a.
Product Manager Sr
epetteruti@chimec.it
Roma,Italy
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Thank you Ernesto.

Original Message:
Sent: 04-11-2023 02:03 AM
From: Ernesto Petteruti
Subject: Scale Modelling

Dear Sahir,
there are different software packages that allow modelling scaling process precipitation in production facilities. In our company we adopted OLIStudio by OLI that has a very sophisticated thermodinamic engine able to model any kind of multiphase fluids also in very high conditions of p,T.
For waht concerns input to the model, of course you need accurate of fluids composition, like water characterization (pH, alcalinity , anions, cations, conductivity, TDS etc.) but also very precise composition of the gas to be treated , and be careful with matching corect saturation of gas with water vapor content, to be able to catch the right phase balance during the production process.
Presence of Barium and STrontium is very important to take under control as deposits of this species (usually they combine with sulphates) is very difficult to get rid of as solubility in standard acids is very poor. Most of the times you will need specific scale inhibitors to prevent any deposition along the circuit of your facilities.

Hope this helps.

Kind regards

------------------------------
ErnestoPetteruti
CHIMEC S.p.a.
Product Manager Sr
epetteruti@chimec.it
Roma,Italy
------------------------------

There are several options to model for the risk of scale formation, taking into account the phase envelope conditions of the gas which may be influenced by the P/T change downhole. However, having said that what other ions are present in the water. High Barium or strontium only may not be a problem if you don't have any sulfate or carbonate or calcium.  Also, the high CO2 in the gas will cause a low pH in the water phase which will reduce the risk of scale. 

To assess the risk of scale or salt deposits, you have to look at the full water chemistry including the chloride level and then run the scale modeling under downhole conditions and surface conditions. 

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WallyGeorgieMaxoil Process SolutionsDirectorwally@maxoilsolutions.com1.832.230.8246Ellon
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Thank you Georgie.

Original Message:
Sent: 04-11-2023 04:44 AM
From: Wally Georgie
Subject: Scale Modelling

There are several options to model for the risk of scale formation, taking into account the phase envelope conditions of the gas which may be influenced by the P/T change downhole. However, having said that what other ions are present in the water. High Barium or strontium only may not be a problem if you don't have any sulfate or carbonate or calcium.  Also, the high CO2 in the gas will cause a low pH in the water phase which will reduce the risk of scale. 

To assess the risk of scale or salt deposits, you have to look at the full water chemistry including the chloride level and then run the scale modeling under downhole conditions and surface conditions. 

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WallyGeorgieMaxoil Process SolutionsDirectorwally@maxoilsolutions.com1.832.230.8246Ellon
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Sahir,

I would be delighted to discuss this with you as we can help you assess your scale risk and potentially provide a best in class, proven, non-chemical solution.

Regards,

JJ

Sahir,

A lot of good comments.  Mine are going to be about your process. 

First, get involved with a good Production Chemist that can run the model. They have learned over time how to tune the models to be more realistic. 

Second, get good water analysis samples from downhole before they have had a chance to start losing ions of possible scales to the flow.  It is very hard to use surface water samples because the saturations have already changed and the results will be misleading.

Third, look at a range of conditions. Model runs are fast and cheap. Look at slightly different water mixes, saturations, and address other uncertainties. Then address changes over time such as depletion, increased water production, different non-compatible water from different zones, etc.  This may be 50 runs.  Each scale will have it's own peak time when it occurs during well life, and where it accumulates.  Your are trying to understand these changes over time.

Finally, get involved with a chemical treatment company or two and look if there is any chemical you can squeeze or deploy in the well to delay or prevent large accumulations.  These chemicals interfere with crystal structure and growth and are highly effective when you have the right ones.

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Dan Gibson
aka The Well Doctor
Completion & Well Integrity Advisor
Houston, Texas
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You need to analyze the CO2 in reservoir water. pH is also essential. So that you model and tell if the problem will be scale or corrosion. 

Also to note is whether the well is having wide PT differential or mixing. 

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Idongesit F. Oduok, MEng, MNSE, MSPE. Whatsapp: +2347037263653. oduok259@gmail.com. Nigeria. PhD student, Chemical Engineering (Flow Assurance)
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Dear Sahir, there are many software platforms available in the market to refine this tipe of calculation with good accuracy. Of course, it is of paramount importance to start the analysis with some reliable data related to brine characterization, gas content (CO2) under well pressure and temperature conditions, and also having clear the geological and geochemical context of the reservoir.

We have good experience in using some of these algorithms and they manage to deliver reliable forecast, of course if initial data are of good quality. Having this type of forecast available covers form the risk of having very challenging scale like barium or strontium sulphate that are quite difficult to get rid of, once they are precipitated.

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ErnestoPetterutiCHIMEC S.p.a.Product Manager Srepetteruti@chimec.itRomaItaly
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Original Message:
Sent: 12-16-2024 07:58 PM
From: Idongesit Oduok
Subject: Scale Modelling

You need to analyze the CO2 in reservoir water. pH is also essential. So that you model and tell if the problem will be scale or corrosion. 

Also to note is whether the well is having wide PT differential or mixing. 

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Idongesit F. Oduok, MEng, MNSE, MSPE. Whatsapp: +2347037263653. oduok259@gmail.com. Nigeria. PhD student, Chemical Engineering (Flow Assurance)
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