An Overview of Surfactant Applications in Drilling Fluids for the Petroleum Industry

Quintero, Lirio

doi:10.1081/dis-120003327

Cited by 14 publications

(25 citation statements)

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“…Non-toxic clay swelling inhibitors are usually used, such as uncharged water soluble low molecular weight polymers or oligomers such as polyethylene glycol (PEG) and polypropylene oxides (PPO), which inclusion rate is up to 10% (Quintero, 2002). These polymers may well function as swelling inhibitors by disrupting hydrogen bonding between water molecule and the silica or alumina functionalities on the clay surface (Quintero, 2002).…”

Section: Composition Of the Acid Washes Solutionmentioning

confidence: 99%

“…These polymers may well function as swelling inhibitors by disrupting hydrogen bonding between water molecule and the silica or alumina functionalities on the clay surface (Quintero, 2002). The glycol molecule, which is capable of hydrogen bonding, is envisaged to compete with water for these sites and also with water hydrating interlayer cations.…”

Section: Composition Of the Acid Washes Solutionmentioning

confidence: 99%

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TOTAL's Experience on the Development and Implementation of a Scale Management Strategy in Central Graben Fields

Baraka-Lokmane¹,

Hurtevent²,

Zhou³

et al. 2014

SPE International Oilfield Scale Conference and Exhibition

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In Central Graben, North Sea, there is generally no free water production, most of the produced water is condensed water; however wells have been treated against scale build up at perforation level by performing acid washes using mainly acetic acid. Wells reacted differently after acid treatment: Some wells showed a significant productivity improvement, others showed good results but limited in time, some wells presented no gain after acid treatment and some other wells are scaling on a more aggressive basis after acidification. This paper shows that these behaviours are linked with the lithology of the different reservoirs. A better understanding on the scale formation and mechanism is essential in order to optimize the well intervention planning and timing to treat the wells. This study showed that calcium carbonate and sodium chloride are the only scale deposits susceptible to precipitate at the bottomholes of wells. The precipitation of sodium chloride has been induced by the high salinity of water associated with a high temperature at bottomholes as well as an inversion of the Joule-Thomson coefficient. Calculations showed that evaporation is slightly higher for Elgin reservoirs comparing to Franklin reservoirs, this is due to Joule-Thomson effect slightly stronger and a higher temperature reservoir for Elgin reservoirs. These high temperatures at the bottomholes induced the formation of calcium carbonate precipitation, this conducted to the loss of productivity. From the subsurface safety valve (SCSSV) to the surface facilities, the reduction of temperature caused a reduction of solubility of zinc sulphide and lead sulphide. In terms of chronology, halite scale occurred first, followed by carbonate scale and finally formation of sulphide scale at lower temperature.

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Section: Composition Of the Acid Washes Solutionmentioning

confidence: 99%

Section: Composition Of the Acid Washes Solutionmentioning

confidence: 99%

TOTAL's Experience on the Development and Implementation of a Scale Management Strategy in Central Graben Fields

Baraka-Lokmane¹,

Hurtevent²,

Zhou³

et al. 2014

SPE International Oilfield Scale Conference and Exhibition

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“…Two of the most important properties to control are viscosity and gel strength. Viscosity and gel strength ate related to [1] removal of cuttings [2] holding cuttings and weight material in suspension when not circulating, [3] releasing cuttings at the surface, [4] reducing to a minimum any adverse effect upon the well bore, and [5] providing information about formations penetrated.…”

Section: Introductionmentioning

confidence: 99%

“…Unfortunately, information on the nature and composition of emulsifiers is scarce. Acidic products from tall-oil, with an average chain length of 18 carbon atoms, other compounds deriving from tall-oil reactions with polyamines [1], as well as alkanolamides, imidazolines and a variety of fatty acids and amines [2] can act as emulsifiers. Similar surfactants are often used in traditional reverse emulsion systems or in synthetic fluids.…”

Section: Introductionmentioning

confidence: 99%

Evaluation of Some Nonionic Surfactants Derived from Tannic Acid as Additives for Water‐Based Mud

Negm¹,

Tawfik²,

Abdou³

et al. 2014

J Surfact & Detergents

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Water-based mud is the most-used mud for oil and gas exploration and is generally considered to be more environmentally friendly than oil-based or synthetic-based mud. Therefore in this study we focused on water-based mud and a series of nonionic surfactants derived from tannic acid was evaluated as additives for water-based muds. The rheological properties for formulated waterbased muds contain nonionic additives at different temperatures were investigated including: apparent viscosity, plastic viscosity, yield point, gel strength, thixotropy and filtration properties. In addition to the relation between shear stress and shear rate were presented at different temperatures. The results of the studied nonionic surfactant showed improvements in the rheological properties when used as additives for water-based mud formulation.

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“…Oilfield waters containing 50-100 ppm barium are not uncommon. Waters with more than 500 ppm sulfate would not contain appreciable amounts of dissolved barium [5,6].…”

Section: Introductionmentioning

confidence: 99%

Estimation of potential barium sulfate (barite) precipitation in oilfield brines using a simple predictive tool

Bahadori

Zahedi

Zendehboudi

2012

Env Prog and Sustain Energy

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Scale deposition is one of the most important and serious problems that limits and sometimes blocks oil and gas production by plugging the oil producing formation matrix or fractures and perforated intervals. One of the most insoluble substances formed from formation water (brine) and one that is very difficult to remove once formed on equipment, formation matrix or fractures and perforated intervals is barium sulfate. It is so insoluble that quantitative analysis methods for both barium and sulfate are based on the precipitation of barium sulfate. In this work a simple‐to‐use predictive tool is developed to estimate potential barium sulfate (barite) precipitation in oilfield brines that are predominantly sodium chloride solutions as a function of sodium chloride concentration and temperature. Estimations are found to be in excellent agreement with reported data in the literature with average absolute deviation being <1.3%. The tool developed in this study can be of immense practical value for experts and engineers to have a quick check of barium sulfate scale formation at various conditions without opting for any experimental trials. In particular, petroleum and process engineers would find the approach to be user‐friendly with transparent calculations involving no complex expressions. © 2012 American Institute of Chemical Engineers Environ Prog, 32: 860–865, 2013

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An Overview of Surfactant Applications in Drilling Fluids for the Petroleum Industry

Cited by 14 publications

References 0 publications

TOTAL's Experience on the Development and Implementation of a Scale Management Strategy in Central Graben Fields

TOTAL's Experience on the Development and Implementation of a Scale Management Strategy in Central Graben Fields

Evaluation of Some Nonionic Surfactants Derived from Tannic Acid as Additives for Water‐Based Mud

Estimation of potential barium sulfate (barite) precipitation in oilfield brines using a simple predictive tool

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