Adsorption/Desorption of Sulfonate by Reservoir Rock Minerals in Solutions of Varying Sulfonate Concentrations

1985 ◽  
Vol 25 (03) ◽  
pp. 343-350 ◽  
Author(s):  
P. Somasundaran ◽  
H. Shafick Hanna

Abstract In micellar flooding, reservoir rocks are exposed to surfactant solutions of varying concentrations as the surfactant slug advances through the reservoir. Therefore, the attachment and detachment of sulfonates with rocks that are already exposed to surfactant solutions of higher or lower concentrations is of major interest. In this study, the abstraction behavior of purified Na-dodecylbenzenesulfonate on Na-kaolinite by stepwise increase in surfactant concentration is determined. Deabstraction* occurring after reductions in surfactant concentrations at various stages also is determined. Most importantly, the results of incremental abstraction, individual abstraction, and deabstraction showed the system to exhibit hysteresis or memory effects. Also, abstractions obtained at various pH values and during stepwise changes in pH exhibited marked differences. The deabstraction isotherms showed the presence of maximum in certain cases, indicating the occurrence of maximum on the abstraction isotherms to be a real phenomenon. Possible reasons for the hysteresis are phenomenon. Possible reasons for the hysteresis are considered, and the practical implications of these memory effects on micellar flooding and depletion experiments using cores are discussed. Introduction Loss of surfactants owing to their interactions with reservoir rocks and fluid is possibly the most important factor that can determine the efficiency of a micellar flooding process. While there has been considerable work with process. While there has been considerable work with dilute surfactant solutions, mechanisms by which surfactants interact with rocks in their critical micelle concentration (CMC) range have not been studied in detail. Nevertheless, some limited data that have been reported in the literature do suggest that the adsorption characteristics of systems made up of concentrated surfactant solutions (above the CMC) are markedly different from those of systems involving dilute solutions. Adsorption isotherms above CMC have been reported to exhibit shapes that have not been encountered elsewhere. Our past work on abstraction of dodecylbenzenesulfonate on Na-kaolinite clearly showed the complex nature of the process, which depends on a number of system variables such as the nature and concentration of inorganic electrolytes, surfactant concentration, pH, and temperature. Under certain conditions, the systems exhibited a maximum in the region of CMC and, in some cases, a minimum at higher concentrations. Most interestingly, the presence of the maximum in the abstraction isotherm depended strongly on the type of inorganic electrolyte in the system. From a practical point of view, it would indeed be useful to be able to control the abstraction of sulfonates by rock minerals by controlling the inorganic electrolytes in the system. However, laboratory batch-type adsorption tests cannot be used directly for micellar flooding systems for a number of reasons. One important consideration in this regard is that the reservoir rocks are exposed to surfactant solutions of varying concentration as the surfactant slug advances through the reservoir. To examine the role of this effect, the abstraction behavior of sulfonates by kaolinite during incremental increase and decrease in surfactant concentration has been determined in this study. Comparison of the abstraction isotherms obtained by conventional batch-type tests (B-isotherms) with those obtained by stepwise changes in surfactant concentration (S-isotherms) and the deabstraction of isotherms of sulfonate upon dilution of the system should help in developing an understanding of the surfactant abstraction behavior as well as the phenomenon of abstraction maximum. Materials and Methods Kaolinite Kaolinite used was a well-crystallized Georgia sample with a B.E.T. surface area of 9.8 m2/g [105 sq ft/g]. Homoionic Na-kaolinite prepared according to a procedure described earlier was used for all the procedure described earlier was used for all the adsorption tests discussed here. Surfactants and Chemicals Sodium dodecylbenzenesulfonate (DDBS) purchased from Lachat Chemical Inc. (specified to be 95 % active but analyzed to be 85 %) was purified in the following manner. purified in the following manner. SPEJ P. 343

2012 ◽  
Author(s):  
Radzuan Junin ◽  
Tahmineh Amirian ◽  
Ahmad Kamal Idris

The adsorption of surfactants from aqueous solutions in porous media is very significant in the enhanced oil recovery (EOR) of oil reservoirs. Surfactant loss due to adsorption on the reservoir rocks weakens the efficiency of the chemical solution injected to decrease the oil–water interfacial tension (IFT). This study investigated the effect of the mineralogical composition of adsorbents on adsorption. Nonionic surfactants were injected into sand packs in which different amounts of clay minerals (kaolinite and illite) were added and compacted in a sand pack holder. The amount of surfactant adsorbed was quantified by subtracting the concentration of surfactants after adsorption from the initial concentration. It was concluded that there is a relationship between the adsorption of nonionic surfactants and the amount of clay mineral in the adsorbents because the quantity of surfactant adsorbed by adsorbents increased when the percentage of clay mineral in the adsorbents increased (from 2 to 8% in the sand packs). The clay mineral illite has a stronger adsorption power for nonionic surfactants than does kaolinite. Key words: Adsorption, reservoir rock minerals, clay minerals, nonionic surfactants


1988 ◽  
Vol 25 (7) ◽  
pp. 1128-1131 ◽  
Author(s):  
J. R. Parker

Studies of thin sections of reservoir rock have been conducted for some time with the goal of understanding flow behavior and estimating physical properties. These sections are essentially two dimensional, but it has always been assumed that the results obtained can be extrapolated to the third dimension. Computer image-processing techniques are often used in this sort of analysis because of the large amounts of data contained in a single digitized section image. One of the methods used to process these images is erosion–dilation, wherein layers of each pore are stripped off (erosion) and then replaced (dilation). This results in a smoothing of the pore perimeters and can be used to estimate pore radii, volume, and roughness. Because of the size of each image, erosion–dilation of images of the pore complex of reservoir rocks is a time-consuming process. A new method called global erosion is much faster, with no increase in memory requirement or decrease in accuracy. This should permit the processing of larger images or a greater number of small images than does the standard method.


1980 ◽  
Vol 11 (1) ◽  
pp. 33-54 ◽  
Author(s):  
Jens-Olaf Englund ◽  
Jan Aug Myhrstad

Within three areas in Southeastern Norway, Lake Mjøsa district, Ås and Moss - Jeløy, groundwater samples for chemical analysis were collected during the years 1971–77 from 98 drilled wells in bedrocks. The water was taken at depths ranging from 15 m to 110 m below the land surface. The groundwater surface is usually present well below the overlying unconsolidated deposits of glacial, glacifluvial or marine origin. The movement of groundwater within the aquifers investigated is so slow that regional changes in water quality is not only dependent on weathering in the unsaturated zone, but also dependent on the solution of reservoir rocks below the groundwater surface. Variations in specific electrical conductance (20°C) largely reflects the different reservoir rock types. The highest values, around 550 μS/cm, are typically found in dark calcareous shales, while sandstones and gneisses give values around 300 μS/cm. The areas Ås and Moss-Jeløy are situated below the Late-Postglacial marine limit. The groundwater is here more or less influenced by ancient sea salts, perhaps also by fossil sea water, left over in sediments or in rock fractures. Brackish groundwater was also found. The composition of groundwater is largely governed by mineral-water equilibria. Most investigated water samples have not reached equilibrium with their surrounding minerals.


2003 ◽  
Author(s):  
Satoshi Ogata ◽  
Keizo Watanabe ◽  
Asano Kimura

Performance of a centrifugal pump when handling surfactant solutions was measured experimentally. The effects of the concentration and temperature of surfactant solutions on pump performance were investigated. It was clarified that the pump efficiency with surfactant solutions was higher than that with tap water, and increased with an increase of surfactant concentration. The value of maximum flow rate of the pump also increased. The total pump head increased with an increase in the surfactant concentration, however, the shaft power decreased with a decrease in the rotational speed of the impeller. The pump efficiency is dependent on the surfactant temperature, and there is an optimal temperature which maximizes the efficiency.


2016 ◽  
Vol 13 (2) ◽  
pp. 87 ◽  
Author(s):  
Saultan Panjaitan ◽  
Subagio Subagio

Hasil penelitian gayaberat di Pulau Biak menghasilkan anomali gayaberat yang dikelompokkan kedalam 2 (dua) satuan yaitu anomali gayaberat 50 mGal hingga 120 mGal membentuk rendahan anomali mencerminkan cekungan. Kelompok anomali gayaberat 120 mGal hingga 220 mGal membentuk tinggian anomali. Pola tinggian anomali sisa 0 mGal hingga 2 mGal diduga sebagai perangkap struktur migas yang terdapat di daerah Kota Biak utara, Mandon dan lepas pantai timur P. Pai. Batuan bertahanan jenis rendah antara 0 - 16 Ohm-meter yang mengindikasikan batuan reservoir jenuh fluida terbentuk di kedalaman 2500 meter. Kedalaman batuan dasar terbentuk antara 7000-8500 meter, dengan rapat massa batuan 2.9 - 3.1 gr/cm3 bertahanan jenis tinggi 1000-8200 Ohm-meter diduga sebagai cerminan dari batuan ultramafik kerak samudera. Batuan yang menyusun di daerah penelitian terdiri atas lapisan batuan Tersier dengan rapat massa 2.45 gr/cm3, batuan Pra-Tersier dengan rapat massa 2.75 gr/cm3 dan batuan dasar dengan rapat massa 3.1 gr/cm3. Batuan sumber adalah serpih Formasi Makat berumur Miosen dengan rapat massa batuan 2.45 gr/cm3, sedangkan batuan reservoir terdiri dari batupasir Formasi Mamberamo. Kata kunci Gayaberat, cekungan, migas, anomali sisa, rapat massa, sesar, antiklin, batuan sumber, tahanan jenis. Gravity research on the island of Biak gravity anomalies are grouped into two (2) units is a gravity anomaly 50 mgal up to 120 mgal is basin reflecting. Gravity anomaly 120 mgal up to 220 mgal formed heights anaomaly. Altitude residual anomaly from 0 mGal to 2 mgal is oil and gas as trapping structures contained in the northern City of Biak, off the east coast Mandon and P. Pai. The rocks is of low resistivity between 0 -16 Ohm-meter that indicates the saturated fluid reservoir rocks are in the depths of 2500 meter. The depth of the bedrock formed between 7000-8500 meters, with density 2.9 - 3.1 gr / cm3 is heights resistivity types of 1000-8200 Ohm-meter interpreted as a reflection of ultramafic rocks oceanic crust. The rocks in the study area consists of Tertiary rocks layers with a density 2.45 gr / cm3, the Pre-Tertiary rocks with density 2.75 gr / cm3 and bedrock with density 3.1 gr / cm3. The source rocks is of shale from Makat Formation Miocene age with density 2.45 gr / cm3, and the reservoir rock consists of sandstone Mamberamo Formation. Keywords: Gravity, basin, oil and gas, recidual anomaly, density, fault, anticline, source rocks, resistivity.


2021 ◽  
pp. 526-531
Author(s):  
Haider A. F. Al-Tarim

The study of petroleum systems by using the PetroMoD 1D software is one of the most prominent ways to reduce risks in the exploration of oil and gas by ensuring the existence of hydrocarbons before drilling.      The petroleum system model was designed for Dima-1 well by inserting several parameters into the software, which included the stratigraphic succession of the formations penetrating the well, the depths of the upper parts of these formations, and the thickness of each formation. In addition, other related parameters were investigated, such as lithology, geological age, periods of sedimentation, periods of erosion or non-deposition, nature of units (source or reservoir rocks), total organic carbon (TOC), hydrogen index (HI) ratio of source rock units, temperature of both surface and formations as they are available, and well-bottom temperature.      Through analyzing the models by the evaluation of the source rock units, the petrophysical properties of reservoir rock units, and thermal gradation with the depth during the geological time, it became possible to clarify the elements and processes of the petroleum system of the field of Dima. It could be stated that Nahr Umr, Zubair, and Sulaiy formations represent the petroleum system elements of Dima-1 well.


1975 ◽  
Vol 15 (1) ◽  
pp. 45
Author(s):  
S. B. Devine ◽  
B. C. Youngs

The Amadeus, Warburton, Officer, Adavale, Arckaringa, Pedirka, Cooper and Great Artesian Basins form a complex system of overlapping basins in central Australia. Cambrian rocks are widespread in the Amadeus, Warburton and possibly the Officer Basins and are marked by the major role of carbonate deposition. Gas and oil shows are known from the Amadeus and Warburton Basins. In South Australia their reservoir potential lies in shoreline clean-up of generally dirty marine sandstones and porosity-permeability associated with archaeocyathid bioherms or dolomitization of limestones.The Ordovician rocks follow the widespread distribution of the Cambrian rocks and are distinctive for thick quartzites and graptolitic shales. In South Australia, the Warburton and Officer Basins may have facies developed which are similar to the Pacoota and Stairway Sandstones, the reservoir rocks for the Amadeus Basin gas and oil fields. Large anticlinal structures have recently been suggested by S.A. Mines Department geophysical work in the Officer Basin which enhances the potential.Red beds are distinctive in the Devonian System. Deposition apparently spilt into the peri-Musgrave Block area and the Adavale Basin to Innamincka area. A thickness of over 3 000 metres of Devonian rocks was drilled in the Officer Basin which contained some reservoir rock lithology. The petroleum potential in South Australia is relatively unattractive.Some 3.4 trillion cu ft of deliverable gas reserves have been established already in the Permian sediments of the Cooper Basin which are up to 900 m thick. The Early Permian sediments of the Pedirka Basin which may be at least 500 m thick may hold similar petroleum potential.


Author(s):  
C. J. Stuart ◽  
L.-C. Liang ◽  
J. B. Toney

A new analytical technique has been developed to allow direct imaging of native-state petroleum reservoir rocks by the use of the scanning electron microscope (SEM) in a low voltage mode combined with a solid-state cryo-system device. The SEM investigation of native-state reservoir rock samples is important since it enables direct visualization of: (1) the spatial distributions of the fluids in the pore system; (2) clay minerals in their natural hydrated states; (3) the native mineralogy; (4) combined effects on the reservoir's wettability and permeability. The technique uses low voltage SEM to image the uncoated surface of the wet sample at a high vacuum and applies the cryostage to control the vapor pressure of the fluid phase while imaging. A differentially pumped environmental chamber is not required with this approach.This technique utilizes a solid-state thermoelectric cooler device (TED) to achieve the required sample cooling. The TED operates on the Peltier principle permitting the surface of the TED to reach a temperature as low as 110 degrees centigrade below its reference temperature. A sample stage is refitted with a TED substage which is water-cooled. The water-cooling of the substage coupled with the TED allows a precise control of the sample temperature. The sample is fixed to the substage so that it is in direct thermal contact with the TED. The TED is then biased (by the use of DC currents) to provide the effective cooling necessary to minimize vaporization of the interstitial fluids in the sample. The sample and stage temperatures are constantly monitored by means of two microtype-K thermocouple devices. With this approach, no liquid nitrogen is needed for this technique.


1979 ◽  
Vol 19 (03) ◽  
pp. 183-193 ◽  
Author(s):  
C.J. Glover ◽  
M.C. Puerto ◽  
J.M. Maerker ◽  
E.L. Sandvik

Glover, C.J.,* SPE-AIME, Exxon Production Research Puerto, M.C., SPE-AIME, Puerto, M.C., SPE-AIME, Exxon Production Research Co. Maerker, J.M., SPE-AIME, Exxon Production Research Co. Sandvik, E.L., SPE-AIME, Exxon Production Research Co. Abstract Surfactant retention in reservoir rock is a major factor limiting effectiveness of oil recovery using microemulsion flooding processes. Effects of salinity and surfactant concentration on microemulsion phase behavior have a significant impact on relative phase behavior have a significant impact on relative magnitudes of retention attributed to adsorption vs entrapment of immiscible microemulsion phases.Surfactant retention levels were determined by effluent sample analyses from microemulsion flow tests in Berea cores. Data for single surfactant systems containing NaCl only and multicomponent surfactant systems containing monovalent and divalent cations are included. Retention is shown to increase linearly with salinity at low salt concentrations and depart from linearity with higher retentions above a critical salinity. This departure from linearity is shown to correlate with formation of upper-phase microemulsions. The linear trend, therefore, is attributed to surfactant adsorption, and retention levels in excess of this trend are attributed to phase trapping.Divalent cations are shown to influence microemulsion phase behavior strongly through formation of divalent-cation sulfonate species. A useful method for predicting phase behavior in systems containing divalent cations is described. This method combines equilibrium expressions with a relationship defining the contribution of each surfactant component to optimal salinity. Observed experimental data are compared with predicted data. Introduction Two essential criteria that must be met for successful recovery of residual oil by chemical flooding arevery low interfacial tensions between the chemical bank and residual oil and between the chemical bank and drive fluid andsmall surfactant retention losses to reservoir rock. If retention is excessive, interfacial tensions eventually will become high enough to retrap residual oil in the remainder of the reservoir.Previous studies have described several mechanisms responsible for surfactant retention in porous media. These include adsorption, porous media. These include adsorption, precipitation, partitioning into a residual oil phase, precipitation, partitioning into a residual oil phase, and entrapment of immiscible microemulsion phases. Of particular interest is Trushenski's discussion of microemulsion phase trapping as a consequence of surfactant-polymer interaction, and a supporting statement that similar behavior often was observed when microemulsions were diluted with polymer-free brine. Here, we attempt to provide some understanding of this surfactant dilution phenomenon by examining phase behavior as a function of salinity, divalent-ion content, and surfactant concentration. Experimental Procedures Surfactant Systems Two surfactant systems were used in this study. (Specific microemulsion compositions are discussed later.) One system was the 63:37 volumetric mixture of the monoethanol amine salt of dodecylorthoxylene sulfonic acid and tertiary amyl alcohol (MEAC12OXS/TAA) described by Healy et al. The oil component for these microemulsions was a mixture of 90% Isopar M TM and 10% Heavy Aromatic Naptha.(TM)** The brine contained NaCl only. SPEJ P. 183


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