Crude Oil - Science topic

Yes, the dissolution of CO₂ in crude oil can increase the energy of elasticity (also referred to as elastic energy storage) of the reservoir formation, but the extent depends on several key factors.

How CO₂ Dissolution Affects Elastic Energy of the Reservoir Formation

1. Volume Expansion of Crude Oil:

o When CO₂ dissolves in crude oil, it reduces the oil viscosity and increases its volume (oil swelling).

o This expansion leads to increased pore pressure within the rock formation, potentially reducing the effective stress on the rock matrix.

2. Impact on Elastic Energy Storage:

o Reservoir Pressure Increase: The expansion of crude oil due to CO₂ dissolution increases pore pressure, which can store additional elastic energy in the rock formation.

o Reduced Effective Stress: If the pore pressure rises significantly, it reduces the effective confining stress (σ' = σ - Pp), which may decrease the rock’s stiffness and elasticity. However, if the rock is already under high stress, the overall deformation may still allow for increased elastic energy storage.

o Compaction and Rock Integrity: If the increased pore pressure remains within the rock’s elastic limit, the formation will behave elastically and store more energy. However, if it exceeds the yield strength of the rock, plastic deformation or fracturing could occur, dissipating energy rather than storing it elastically.

Considerations in Energy Storage and Elasticity

• Rock Type: Carbonate formations and sandstones respond differently. Highly compressible formations may exhibit more elastic energy storage due to CO₂-induced pore pressure increases.

• Pore Fluid Interactions: The interaction between CO₂, crude oil, and formation water alters the wettability and capillary forces, influencing the overall stress distribution and elasticity.

• CO₂ Concentration & Saturation: Higher CO₂ dissolution may lead to greater expansion, increasing the stored elastic energy up to a certain threshold before inducing structural instability.

Conclusion

Yes, the dissolution of CO₂ in crude oil can enhance the elastic energy of the reservoir formation by increasing pore pressure and inducing oil expansion. However, if the pressure increase is too high, it could lead to plastic deformation or even fracturing, which would dissipate stored elastic energy instead of enhancing it. The overall impact depends on the rock’s mechanical properties, fluid interactions, and pressure conditions.

I recommend you to visit the following papers;

They are well articulated, have a look they might be very useful

President Donald Trump has announced that he will impose 25% tariffs on imports from Canada and Mexico. However, whether crude oil will be included in these tariffs remains unclear. Trump mentioned that oil "may or may not" be covered by the tariffs and that a final decision would be made soon. The uncertainty around this decision has significant implications for both the U.S. and Canadian economies, particularly in terms of energy prices and trade relations

Common seawater pollutants that trigger bacterial growth include crude oil, sewage, plastic pollution, and potentially chemicals from sunscreens. These substances provide carbon sources or alter environmental conditions, promoting bacterial proliferation in marine ecosystems.

Converting an existing pipeline designed under ASME B31.4 to transport multiphase commodities, such as natural gas and crude oil, involves several critical considerations. Here's a list of key factors to address:

1. Review Applicable Codes and Standards

2. Multiphase Flow Dynamics

3. Pipeline Design and Integrity

4. Flow Stability

5. Pipeline Modifications

6. Hydraulic and Mechanical Analysis

7. Pipeline Materials

8. Safety and Risk Management

9. Regulatory Compliance

10. Operational Considerations

Summary

Converting a pipeline to multiphase service involves a holistic assessment of flow dynamics, mechanical integrity, material compatibility, and operational risks. A detailed engineering analysis and possibly modifications to the pipeline and auxiliary systems will be necessary to ensure safety, reliability, and compliance. Engaging experts in flow assurance, corrosion, and pipeline design is recommended for this complex transition.

There are so many reviews and articles regarding your issue, please go through, as the problem you have mentioned is not a new attempt

Skew–Brownian processes are used to model asset prices, such as crude oil Brent, by incorporating asymmetry and jumps in their dynamics. They can help estimate volatility by capturing skewness in price movements, providing a more accurate reflection of market behavior compared to traditional Brownian motion models. This approach can enhance the precision of volatility estimates and improve risk management strategies.

I found these papers : and

They mention the source of their data and one include it in the appendix. Good luck!

Acids like nitric and sulfuric acid carry out the process of digesting crude oil. These potent acids can have an impact on the raw materials used to make prope, according to experts.

Resins are thought to be molecular precursors of the asphaltenes. The polar heads of the resins surround the asphaltenes, while the aliphatic tails extend into the oil, At the onset of precipitation, asphaltenes form linear and planar aggregate structures, while after sufficient precipitation they become more three dimensional. asphaltenes are insoluble in an excess of heptane (or pentane) whereas resins are miscible with heptane (or pentane).The solubility of asphaltenes in this epoxy resin, the rheological properties of the mixtures, and the effect of asphaltenes on the curing with 4,4′-diaminodiphenyl sulfone . the glass transition temperature, strength, and adhesion characteristics of the asphaltene- the asphaltenes simultaneously plasticize and reinforce the polymer matrix, and the transition from predominant plasticization to strengthening occurs with an asphaltene content at 20 wt%.

**Extraction of crude oil and its derivatives**

* **Pollution during extraction:** Drilling, refining and extraction processes produce emissions of greenhouse gases, sulfur dioxide, nitrogen oxides and particulate matter. In addition, offshore drilling can pollute the water and harm marine life.

* **Pollution during use:** When fossil fuels are burned, they produce carbon dioxide, sulfur dioxide, nitrogen oxides and other pollutants that contribute to air pollution and climate change.

* **Pollution during disposal:** Crude oil and its derivatives can leak into the environment during transportation and storage, causing soil and water pollution. In addition, methane and carbon dioxide can be emitted from landfills containing petroleum products.

**Lithium extraction and disposal**

* **Pollution during extraction:** Lithium extraction from salt mines or brines can cause water consumption and air pollution due to dust. In addition, lithium can leach into groundwater, harming plants and animals.

* **Pollution during use:** The use of lithium batteries does not produce any direct emissions. However, the production of lithium batteries requires large amounts of energy, which can generate emissions if obtained from fossil fuel sources.

* **Disposal:** Lithium batteries can be recycled, but the process is complex and can be expensive. If batteries are disposed of in landfills, lithium may leak into the environment and cause soil and water pollution.

**Conclusion**

The extraction of crude oil and its derivatives pollutes the environment at all stages of its life cycle, from extraction to use and disposal. Although lithium extraction can also cause pollution, the environmental impact of lithium battery production is much lower than that of fossil fuel production and use. Additionally, lithium batteries can be recycled, reducing their overall environmental impact.

However, it is important to note that both industries have an environmental impact and we must continually strive to find ways to reduce this impact. This includes investing in renewable energy sources and developing more sustainable technologies to extract, use and dispose of lithium.

Methods for identifying microorganisms that degrade crude oil include the following:

1. Spectrophotometric Method: Degradation of crude oil and purified hydrocarbons by bacterial and fungal isolates can be detected using this method.

2. 2,6-Dichlorophenol Indophenol (DCPIP) Method: This redox indicator can be utilized to screen for potential crude oil degrading microbes in a straightforward and rapid manner.

3. Hydrocarbon Analysis via GC–MS: This method can furnish comprehensive insights into the degraded oil's composition.

4. PCR: This method can be used to detect genes implicated in hydrocarbon degradation, such as AlkB and PMO, in microbial communities.

Detergent waste is a serious threat to water,The detergents reducing the natural water quality, pH changes in soil and water, eutrophication, reducing light transmission, and increasing salinity in water sources. Many laundry detergents contain approximately 35 to 75% phosphate salts. Phosphates can cause a variety of water pollution problems. In wastewater treatment plants, detergents from residential wastewater are removed through a combination of physical, chemical, and biological processes. Liquid laundry detergents can be made biodegradable and eco-friendly by including alkyl polyglucosides, polyoxyethylene lauryl ether, and a thickener. Choose phosphate-free detergents, soaps, and household cleaners.

Thank you very much for your answer@ Morteza Asemani

📷Environmental Engineering Science

Environ Eng Sci. 2012 Jun; 29(6): 494–501.doi: 10.1089/ees.2010.0490PMCID: PMC3363014PMID: 22693416Treatment and Remediation of Petroleum-Contaminated Soils Using Selective Ornamental Plants Rui Liu,1,* Rajendrasinh N. Jadeja,2 Qixing Zhou,1,,3,* and Zhe Liu1Author information Article notes Copyright and License information PMC DisclaimerGo to:Abstract Pot-culture experiments were carried out to assess the phytoremediation potential of 14 ornamental plants in weathered petroleum-contaminated soil, which was collected in the Shengli Oil Field, one of the biggest oil fields in China, by examining their impact on the degradation potential of total petroleum hydrocarbons (TPHs) and its composition. Results showed Gaillardia aristata, Echinacea purpurea, Fawn (Festuca arundinacea Schreb), Fire Phoenix (a combined F. arundinacea), and Medicago sativa L. could effectively reduce TPHs and its composition in 10,000 mg kg−1 TPH-contaminated soil. After a 30-day pot-culture experiment, the removal rates were 37.16%, 46.74%, 49.42%, 41.00%, and 37.93%, respectively, significantly higher than that in the control (only 12.93%). Removal rates of TPH composition including saturated hydrocarbon, aromatic hydrocarbon, asphaltene, and polar compound reached 39.41%, 38.47%, 45.11%, 42.92%, and 37.52%, respectively, also higher than that in the control (only 6.90%). Further, the total biomass did not significantly decrease for all plants tested in 10,000 mg kg−1 TPH-contaminated soil. Fourier transform infrared spectroscopy confirmed the presence of oil in the plant tissues. These results suggested that the typical ornamental species including G. aristata, E. purpurea, Fawn, Fire Phoenix, and M. sativa can be adopted in phytoremediation of oil-contaminated soil.Key words: : phytoremediation, total petroleum hydrocarbons (TPHs), petroleum-contaminated soil, ornamental speciesGo to:Introduction With rapid development of industry, automobiles, and airplanes, the demand for petroleum is increasingly expanded. However, plenty of petroleum was impregnated to soil during the exploration, translocation, and processing, and it caused significant environmental pollution (Environment Agency, 2002; Banks et al., 2003). According to relevant reports, the concentration of total petroleum hydrocarbons (TPHs) around the Liaohe Oil Field may be more than 10,000 mg kg−1, rather higher than the risk-based cleanup levels (500 mg kg−1) in industrial soils for TPHs in Oklahoma, United States (Cao and Li, 2010). The levels of TPHs around the highly contaminated sites were 30%–50% in the surface soil (0–20 cm) (Cunningham et al., 1996; Sun and Zhou, 2007). As a result, the toxic effects of TPHs have been extensively documented; the research on petroleum-contaminated soil has been paid great attention (Zhou et al., 2005).Typical treatments for petroleum-contaminated soil involve in excavating the soil and removing it for treatment using physical or chemical methods (Zhou, 1995; Li et al., 1997; Hans-Holgar and Alexander, 2000; Juck et al., 2000). These treatments, though effective, are costly and involve in extensive site disturbance. To find more financially acceptable options, biological methods have been investigated, such as phytoremediation, that is, using living green plants in situ to “clean-up” contaminated lands. Phytoremediation is a low-input approach depending on natural attenuation by biodegradation and physiochemical mechanisms that decrease the pollutant concentration wherein sowing plants may be the only intervention (Schwab et al., 1999; Liste, 2000; Joner and Leyval, 2001; Muratova et al., 2003; Robson et al., 2004; Zhou and Song, 2004; Parrish et al., 2005).In the past decade, it has produced an extensive body of research on the phytoremediation of both organic and inorganic contaminants (Chaîneau et al., 1997; Dzantor et al., 2000; Singer et al., 2003; Smreczak et al., 2003; Rentz et al., 2004). Most hydrocarbon degradation is believed to occur through a rhizosphere effect; plants exude organic compounds through their roots, which increase the density, diversity, and activity of specific microorganisms in the surrounding rhizosphere, which in turn degrade hydrocarbons (Siciliano and Germida, 1998; White et al., 2003; Rutherford et al., 2005). Few studies only by Zhou and coworkers (Peng et al., 2009; Cai et al., 2010; Zhang et al., 2010), however, have examined ornamental plants for phytoremediation of petroleum-contaminated soils. This has their advantages in revegetation cover and beautifying surrounding environment. Phytoremediation using ornamental plants can avoid entering food chains and effectively reduce the pollution, than using crops. The aim of this work was to screen out ornamental plants with high effectiveness for treating petroleum-contaminated soil, by examining the removal rate of TPHs and its composition after a 30-day pot-culture experiment in TPH-contaminated soil.Go to:Experimental Sampling and tested materials Weathered petroleum-contaminated soil was collected (sampled to a depth of 250 mm) from the Shengli Oil Field in Dongying City, Shandong Province, China. Soil analysis was done by the Key Laboratory of Terrestrial Ecological Process, Institute of Applied Ecology, Chinese Academy of Sciences, Shenyang, China. The contaminated soil had been classed as a drained brown soil with pH 7.66, and carbon (C), phosphorus (P), nitrogen (N), and available P concentrations were 45.77, 0.65, 0.73, and 0.002 g kg−1, respectively. Uncontaminated reference soil samples were collected from the Wanliutang Park, Shenyang, China. The average concentration of TPHs in contaminated soil collected was 28,000 mg kg−1 and its composition of TPHs was 40.76% of saturated hydrocarbon fraction, 27.02% of aromatic hydrocarbon fraction, and 30.82% of asphaltene and polar fraction. Collected soil was sieved through a 4.00-mm sieve to ensure homogeneity. According to the pretest results, all plants tested could not grow in the weathered petroleum-contaminated soil directly. Through the addition of uncontaminated reference soil, contaminated soil collected was diluted to 10,000 mg·TPHs kg−1 (WTPHS/Wsoil) according to the experimental design.The tested seeds of plant species were purchased from Kelaowu Seeds Company, Beijing, China.Experimental design The tested plants and their basic botanical characteristics are summarized in Table 1. Soil tested (2.5 kg) was added to 20-cm-diameter pots. A disc of filter paper was placed in the bottom of each pot to prevent the dry soil escaping out from the drainage holes and pots were placed on saucers. To each pot, single plant species treatments (n=6) were transformed, and germination of each seed took place in 15 days. . . . "

See the entire article - Source:

Please check if this is helpful- https://rdrr.io/cran/riskR/man/risk.hedge.html

I believe these may vary depending on the crude oil properties, ambient environment and pipeline parameters. There are some formulas in the literature. I encourage you to do a search and study them. Better to perform your own experiments if you can.

Let me know how you get on as I am working on a similar topic.

That may add to the broader spectrum of your Reenu Kumari research, with respect to economic growth, wealth and energy.

Thanks, so much, Mohammed and Komeyi.

Hello,

In addition to the previous answer, you can try running the crude oil on a size exclusion column, separating the elution fraction into several sub-fractions, and analyzing each sub-fraction on the HPLC individually.

Thank you so much Dr Atul, can you explain more what i will do , with regards

Think you'd do better with broth enrichment than direct plating.

Please don't presume that growth indicates "crude" degrading microbes.

If you use ATR, the title of your y-axis should read "reflectance" (and not "transmittance"). Now we need to know how the reference measurement was performed - this is absolutely essential, since quite often this is the problem!

Using chaos theory, a change in price is determined through mathematical predictions of the following factors: a trader's personal motivations (such as doubt, desire, or hope, all of which are nonlinear and complex), changes in volume, the acceleration of changes, and momentum behind the changes.

Kabiru Adebayo

You should always do what the RG recommends. You need to click on "mention". I accidentally saw an appeal to me.

The method suggested earlier will not work for you.

You must definitely remove the soil, then extract the oil with a solvent from the soil. The kerosene fraction is best suited as a solvent.

I am answering myself, but still, it may be useful as a reference. Menu Drawing\StreamBox and tick Petroleum Assay in Properties.

Ok@Arunaditya Sahay ,I will do that, thank you sir.

you can increase the viscosity by decreasing the temperature

We certainly need new and creative ideas along with changes in behavior if we are to effectively move into the future and avoid crises, as energy is such a large part of modern civilization. This requires constructive dialog and facing difficult facts. Sadly, Western Society is increasingly less able to discuss anything intelligently, let alone constructively. Much of what we see today (especially on social media) could be described as: state your position in three words or less that will preclude any meaningful discussion and also vilify everyone else in the room. The pandemic has only made it worse, when it should have been a wake up call to remind us how much we need to pull together.

We should never include a static variable in panel data which does not change. You have mentioned that you wish to measure the impact of crude oil price change on the cost. The change can be taken in form of first differences stored in a variable when the data is arranged company wise with years.

In order to obtain fractions as components for diesel, you may conduct distillation at atmospheric pressure and in vacuum (for diesel components), but I think maybe it's better to carry out a hydrotreating step, to eliminate the olefins formed during the pyrolysis. In that way, you can have a higher yield in C15-C18.

I believe the outcome of the treatment process largely dependent on two key factors: The nature of the adsorbents and catalyst used that is to say their morphological characteristics and the nature of the contaminants. This variations and disparity might be responsible for the wife differences in their removal efficiencies

you can read:

I asked that question to the person who code that package, and he said C(9) coefficient does not have any meaning here, just ignore. It comes up because the package is written for the old version of Eviews and has not been updated that is why.

Thank you Dr. Rawaa

Radwan Bu Haram

check the file

Do you need to define oil in water or water in oil, and in which range.

I see that the three answers focused on determining the amount of water on oil but I understand from your question that you are looking for technics for measuring oil in water. For that you can use oil&grease, TOC, COD or similar methods.

Dear Sara Shokranian,

Raman spectroscopy is usually used to study different crude oils in the (1200—2000) wavenumber range. Moreover, crude petroleum oils are typically excited using ultraviolet wavelengths (300–400 nm) and fluoresce in the visible wavelength range from 400 to 600 nm.

I syggest you to use UV quartz cuvette, as well as scan the sample from (200-700 nm) to obtain the max or the best wavelength of absorbance for your sample.

Use above link to purchase the crude oil

Ahh Bugs replacing refinery process again. A 50+ year old dream that will probably come true some day - but probably not in my lifetime.

Based on your descriptions, it is likely that the extraction time is insufficient for the extraction to be completed. However, it would be difficult to conclude based on color observations. You can try several steps:

(1) Increase the extraction time

(2) Reduce the physical size and / or amount of samples used for extraction

(3) Spike surrogate / internal standards into your samples and cross-check for recovery

In this article we look at these issues, I hope you find it of interest.

After Impregnation, dry sample at 100 oC for 24 - 48 hours (you can also reduce in a muffle oven at say 250 oC). Then spatter coat sample and perform your SEM analysis.

The cut temperature is taken from the probe is placed on the top of the jacketed column connected over the Distilling Flask. You can refer to the picture here. https://brinstrument.com/blog/crude-oil-distillation/true-boiling-point-distillation-astm-d2892-distillation-of-crude-oil/

Hello.

Although the equations you mention can help outline the approximate extreme leakage, the scenario you have laid out is quite complex and depends on many factors such as: the pipe diameter, length and slope of the flowline, as well as the initial flowrate (velocity and momentum of the fluid), fluid PVT and ambient conditions (temperature and pressure of the system outside of the pipe compared to inside).

You are correct that CFD software is not designed for this type of analysis, in industry I would recommend a transient pipeline flow simulation software such as OLGA or Ledaflow.

Depends where you are on the HLD scale. All salts, including NaCl effect the HLD, and thus the interfacial tension of surfactant-oil-water systems. At HLD=0 (phase inversion point) the system undergoes lowest IFT and as you move away from it, the IFT increases.

Dear Dr Olubukola

Please kindly follow the references, hope they can be useful for your study;

Best wishes

https://ttu-ir.tdl.org › handlePDF

نتائج بحث الويب

COEFFICIENT OF ISOTHERMAL OIL COMPRESSIBILITY FOR ...

Food Grade LUbricants contain greater than 90% MOSH and it may contain high levelos of MOAH too. Hence usage of FG lubricants is not the way to achieve low levels of MOSH and MOAH in rfefined oils.

because it is more convenient and more indicative

non to my knowledge

Nurbol Bekbossinov you are exactly right on some of the key challenges. Due to the supercomplex nature of petroleum, there are limitations in every method. the most effective way is probably the divide-and-conquer strategy, i.e., chromatographic separation followed by characterization techniques. The well known and popular average structure strategy (use one or few representative structures to represent any petroleum fraction) based on NMR, MS etc. is obviously very limited because so many molecules. The high res MS can reveal up to a quarter million ion peaks easily, and probably the closest to understand the reality of petroleum species. However, we still don’t know exactly how many molecules in petroleum since each MS peak can represent many molecules and each formula has a gazillion of possible structures. so, we really don’t know about exactly the structures unless there is a method to isolate individua molecule and characterize them, which is probably impossible. Most of the structures in papers or textbooks so far are still “cartoons“ or schematics, i.e. they represent numerous structures. The only approach to provide real and specific structures had been the recent non-contact Atomic Force Microscopy technique in the last few years which allows us to take a “look“ at individual molecules directly. You can take a look at this paper to start with.

In basis of my experience, as much as HLB of surfactant is less, the potential of foam generation and foam stability is higher. CMC is a function of HLB, but even high HLB surfactants can provide ultra-low IFT conditions at usually high concentrations. For example: SDBS is an anionic surfactant with HLB ~ 21, however, it can provide the IFT values less than 1 mN/m (0.82 mN/m) at 5000 ppm (CMC) [10.1021/acsomega.0c04464].

In other words, the topic of foam is not as dependent on IFT as it is on HLB.

You should start researching such basic questions by first doing a keyword search on Google (or any search engine). Many free review papers, journal articles and application notes can be found in this way. Learning how to research a question is one of the most important skills you can learn as a student.

Many types of useful crude oil analysis methods for GC have been published starting in the 1960's by the EPA and many other groups, such as the AOCS to name a few. Improvements and variations are plentiful. Depending on the exact area of crude oil analysis or the type of comparison needed, different columns and methods are used.

dear Suresh Kumar Govindarajan

find the english files there

Is the dilution equation required in this situation?

I think, this question is more interesting. I can say, that asphaltenes are soluble in aromatics solvent, because they have unical colloidal properties. Aromatic solvents may dissolve polyaromatic molecules because p-p interactions, and delocalization electronic structure of this colloidal structure. Symmetrical molecules of solvent have equally dipole moment and don't displace or dislocate electronic balance of asphaltenes. There are a lot of papers about fractionation and solvatation of asphaltenes in different solvents. The nature of asphaltenes are related with their electronic structure.

Petroleum Refining Technology and Economics Fourth Edition. James H. Gary. Chapter 12.

There is possibility that the volatility of the crude price will remain the same.

Nam Nhat you can find it in books (a lot of ebooks are available). Secondly check the patents they are available free of charge (for example google patents).

regards,

GB

Depending on the method used for extraction

In this respect you are planing GC. The difference is just in detection way after the chromatography column. In case of FID you may apply it since you have your system calibrated for each compound with chromatopghaphic standards. If is for quality control I suggest it since after calibration it is quite easy to check retention times and peak areas with the GC software.

In case of using GC coupled to MS you avoid calibration and therefore the spend of standards, and then compare with MS catalogue. It is therefore more accurate than using FID.

Here is the TBP (15/5) distillation procedure. It is not usually used on naphtha

https://www.astm.org/Standards/D2892.htm. A"Sim-Dist" D2887 is typically used instead.

Ahmad K. Sleiti yes the grid part is well resolved and it is independent of grid setup!

Dear Ashish Thakur, the electricity is produced mostly based on carbon fuels (coal, gas and oil) combustion, therefore, these are considered as a primary source of energy. I once have read that diesel engine was a revolution because on the glass of oil you can drive about 2 km...

My findings is not just limited to SMS, fish wastes etc, palm oil mill effluent has been used effectively for bioremediation studies because of the consortium of microbes capable of degrading spilled oils on soils as energy sources...so much more

Thank you researcher Binod Timalsina for your suggestion. This paper gave me lots of ideas about DCPIP test.

Please go to this link:

Dear Jawad,

The accuracy of your results will depend on the method or methods used to determine the oil content. Simple, cheap and fast methods are usually more sensitive for interferences resulting in strange or incorrect results than more elaborate complicated and time consuming methods. Do spent time in validating methods before applying them.

follow

Well,

On the issue of pollution treatment, the golden rule says (treat the source of pollution) means cutting the source of leakage from the pipe.

Regards

The line required for corrosion protection while the nature of multiphase pipelines is such that the combined use of protective coatings with cathodic protection is necessary to achieve the effective protection. In fact, protective coatings help control pipeline corrosion by providing a barrier against reactants such as oxygen and water. But, because all organic coatings are semipermeable to oxygen and water, coatings alone cannot prevent corrosion and so a combination of cathodic protection is often used.

Zhang Shiming, for the reason that you are talking about “reservoir”, and we use geophysics methods to characterize the reservoirs, please, let me share from the geophysicists´ point of view some aspect of the salt influence on oil reservoirs such as you are asking at the RG community.

The existence of evaporite deposits, follow the meaning of “salt” explain before by Ashkna Vafadar, has too much influence, such as:

First, the salt bodies behave in a different way than more typical sedimentary rock types. One of the key factors is that salt is much weaker than other lithologies: Salt deforms as a viscous material that effectively flows.

Also, salt has a nearly constant density irrespective of burial depth. This contrasts with sediment that becomes denser upon burial. Salt compactation trend, and compactation effects are different of the other sedimentary rocks.

Salt rocks have a great range of compressional P-wave velocity: e.g., 5800 to 6200 m/s for anhydrite and 3000 m/s for silvinite (Mavko et al., 2009).

Porosity on salt rock is almost irrelevant. In fact, through well log analysis, changes in salt velocity may be associated to proportional of salt rock type and its composition within limits of well log tool detection than to stress effect.

As salt rocks as halite, carnalite, tachyhydrite and silvinite have plastic behavior under deviatoric stress. Identifying these salt rock would avoid trapped and collapse in the operations.

Sub-salt seismic imaging demand PSDM (prestack depth migration) since salt plays such a velocity inversion, for example.

Due that the salt has a higher thermal conductivity in comparison with the average conductivity of the most of sedimentary rocks, the existence of salt plays a critical role in the maturation of the source-rocks, in function of the relative position of the sedimentary rocks around the salt: below the salt, the source rocks maturation can be retarded, whereas above the salt, the source rocks maturation could be enhanced.

Due that the existence of an exceptional geophysical set of relative contrast properties on the presence of salt bodies (magnetic and gravity signature) a low-cost tool such as aeromagnetic / aero gravimetric survey can help you to predict the existence and thickness of salt bodies, a crucial component to defining oil and gas prospects.

The changing geometry of salt also plays a key-role in regulatory the evolution of fluid migration pathways through time. Another influence relative to the geometry of salt bodies are related with the migration pathways, seals to trap in a petroleum system.

I hope this answer help you to understand the role of "salt" evaporite bodies in reservoir characterization.

Best wishes, Mario

The price of oil is shaped by supply and demand. Due to the coroner's crisis, the demand for oil internationally has collapsed and with it the prices. Small and large businesses order less oil, airline fleets remain stuck on the ground and consumers stay home and do not use their vehicles.

These are the so-called May contracts, which expired on April 21. Which means that whoever owns such a contract that day, also owned the agreed amount of oil. However, oil reserves are high, so the cost of additional storage increases. For this reason, investors turned their backs on fixed-term contracts, which not only lost their value, but their prices fell to negative levels.

Speculators may be interested in time contracts because they are essentially betting on future price formation. They can therefore make or lose money. There are many speculators who have been lost these days. Many companies want to secure their transactions in the fossil fuel market so that they know in advance how much they will have to calculate. Only at this time no one wants oil, the delivery of which is guaranteed by the deadlines.

WTI (West Texas Intermediate) crude oil has limited storage capacity, as the pipelines end up in Oklahoma, where the world's largest storage facility is located in the city of Cushing. But there the spaces are already full and extra space costs about ten dollars per barrel. And it is not ruled out that their price will increase further. It should be noted that for the European type of Brent oil there are more storage possibilities.

Oil companies will face problems if prices remain so low. This could have an impact on loan service as well as employment. Low prices are pushing the sluggish production sector to the brink of bankruptcy. Observers estimate that these companies need a barrel of $ 50 to cover their costs.