scholarly journals Design and characterization of a microbial self-healing gel for enhanced oil recovery

RSC Advances ◽  
2017 ◽  
Vol 7 (5) ◽  
pp. 2578-2586 ◽  
Author(s):  
Jun Wu ◽  
Hou-Feng Wang ◽  
Xian-Bin Wang ◽  
Hai-Yang Yang ◽  
Ru-Yi Jiang ◽  
...  
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Self Healing ◽  
Sweep Efficiency ◽  
The Poor ◽  
Crude Oil Production

Due to the heterogeneity of rock layers, the poor volumetric sweep efficiency of water and an invalid cycle have emerged as major problems in crude oil production.

scholarly journals METHODS OF INCREASING PROJECT LEVELS OF CRUDE OIL PRODUCTION AT THE DEVELOPMENT OF MULTILAYER DEPOSITS

2017 ◽  
pp. 95-101
Author(s):  
V. V. Panikarovskii ◽  
E. V. Panikarovskii
Keyword(s):  
Hydraulic Fracturing ◽  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Injection Wells ◽  
Crude Oil Production

A brief review of the work on intensifying the inflow and increasing the oil recovery of the Neocomian deposits of the Priobskoye field is expounded. The analysis of technologies for increasing oil recovery of AS10, AS11, AS12 is performed. The technology of hydraulic fracturing in production and injection wells and methods of selecting wells for hydraulic fracturing in the operational well stock of the Priobskoye field are considered. Based on the analysis of enhanced oil recovery technologies, the need for hydraulic fracturing in low-productivity reservoirs has been proved.

A Comprehensive Review of Thermal Enhanced Oil Recovery: Techniques Evaluation

2018 ◽  
Vol 141 (3) ◽  
Author(s):  
Esmail M. A. Mokheimer ◽  
M. Hamdy ◽  
Zubairu Abubakar ◽  
Mohammad Raghib Shakeel ◽  
Mohamed A. Habib ◽  
...  
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Production ◽  
Economic Benefits ◽  
Comprehensive Review ◽  
Second Stage ◽  
Energy Demands ◽  
Recovery Techniques ◽  
Third Stage

The oil production from any well passes through three stages. The first stage is the natural extraction of oil under the well pressure, the second stage starts when the well pressure decreases. This second stage includes flooding the well with water via pumping sea or brackish water to increase the well pressure and push the oil up enhancing the oil recovery. After the first and secondary stages of oil production from the well, 20–30% of the well reserve is extracted. The well is said to be depleted while more than 70% of the oil are left over. At this stage, the third stage starts and it is called the enhanced oil recovery (EOR) or tertiary recovery. Enhanced oil recovery is a technology deployed to recover most of our finite crude oil deposit. With constant increase in energy demands, EOR will go a long way in extracting crude oil reserve while achieving huge economic benefits. EOR involves thermal and/or nonthermal means of changing the properties of crude oil in reservoirs, such as density and viscosity that ensures improved oil displacement in the reservoir and consequently better recovery. Thermal EOR, which is the focus of this paper, is considered the dominant technique among all different methods of EOR. In this paper, we present a brief overview of EOR classification in terms of thermal and nonthermal methods. Furthermore, a comprehensive review of different thermal EOR methods is presented and discussed.

scholarly journals Iran’s crude oil reserves and production

GeoArabia ◽  
2007 ◽  
Vol 12 (2) ◽  
pp. 69-94 ◽  
Author(s):  
Moujahed I. Al-Husseini
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Oil Production ◽  
Improved Oil Recovery ◽  
Total Recovery ◽  
Recoverable Reserves ◽  
Crude Oil Production ◽  
Decline Rate ◽  
The Government ◽  
Giant Fields

ABSTRACT The Government of Iran estimates the country’s initial-oil-in-place and condensate-in-place are about 600 and 32 billion barrels (Gb), respectively. In 2004, the official estimate of the proved remaining recoverable oil and condensate reserves was about 132.5 Gb, of which crude oil accounted for about 108 Gb. Cumulative crude oil production is expected to cross the 60 Gb mark in 2007, implying that the estimated ultimate recoverable reserves of crude oil are about 168 Gb (cumulative production plus remaining reserves) and the total recovery factor is about 28%. The main Oligocene-Miocene Asmari and Cretaceous Bangestan (Ilam and Sarvak) reservoirs contain about 43% and 25%, respectively, of the total crude oil-in-place. Recovery factors for the Asmari range between about 10–60%, and for the Bangestan between 20–30%. Between 1974 and 2004 remaining recoverable reserves have increased from about 66 to 108 Gb, while the ultimate recoverable reserves have increased from 86 to 168 Gb. In contrast to 1974 when Iran’s production peaked at 6.0 Mb/d, production in 2005 averaged about 4.1 Mb/d. The 1974 peak occurred when production from most of the giant fields was ramped-up to very high but unsustainable levels. Current plans are to increase the crude oil production rate to 4.6 Mb/d by 2009. This is a significant challenge because this production capacity has to offset a reported total annual decline rate of 300–500,000 barrels/day (Kb/d). This high decline rate is attributed to the maturity of the giant fields, many of which attained their peaks in the 1970s and have produced about half or more of their estimated ultimate recoverable reserves. Therefore to achieve the 2009 production target within the next three years, Iran has to add about 680 Kb/d of capacity per year from its developed fields (infill drilling, recompletions, enhanced and improved oil recovery), while also adding net new surface facilities and well capacity from undeveloped fields and reservoirs.

scholarly journals ANALISIS PENGGUNAAN LISTRIK ARUS SEARAH UNTUK MENINGKATKAN LAJU PRODUKSI MINYAK BUMI JENIS MINYAK BERAT

2018 ◽  
Vol 9 (2) ◽  
pp. 141-146
Author(s):  
Redaksi Tim Jurnal
Keyword(s):  
Crude Oil ◽  
Direct Current ◽  
Oil Recovery ◽  
Oil Quality ◽  
Electrical Power ◽  
Oil Production ◽  
Heavy Crude Oil ◽  
Technology Application ◽  
Crude Oil Production ◽  
Heavy Crude

rom EEOR, Electro Enhanced Oil Recovery, and a developing technology application which has been established earlier. The difference is ESOR relatively does not improve recovery factor of producing well. Ideally any crude oil producing well will be experiencing pressure decline which may affect crude oil production decrement, naturally. Regarding some similar researches around the world, the use of direct current electrical exposure was proven to increase number of heavy crude oil production. At least salinity, hydrocarbon chemical compounds and crude oil flow in the reservoir (electro-osmosis) involves during chemical processes in the reservoir while ESOR application. Number of electrons conducted from direct current electrical power supply will be a supporting media during chemical process of these parameters. Unfortunately after completing ESOR application in Lapangan X, the result was contradictive with this research hypothesis. Exposure of direct current electrical supply did not increased heavy crude oil production. On a contrary, parameter of salinity and API gravity as produced heavy crude oil quality, were improving significantly.

scholarly journals Solvent Blend Performance in Hydrocarbon Recovery from Nigerian Tank Bottom Sludge

2016 ◽  
Vol 9 ◽  
pp. 20-28 ◽  
Author(s):  
Elijah A. Taiwo ◽  
John A. Otolorin
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Oil Sands ◽  
Room Temperature ◽  
Oil Production ◽  
Extraction Process ◽  
Improved Oil Recovery ◽  
Hydrocarbon Recovery ◽  
Crude Oil Production ◽  
Tank Bottom

Oil sludge waste associated with crude oil production generally consists of oil, sands and untreatable emulsions segregated from the production stream, and sediment accumulated on the bottom of crude oil and water storage tanks. The use of single solvent and combination (solvent blend) was evaluated for extraction of hydrocarbon content (oil) of the Tank Bottom Sludge (TBS) associated with the crude oil production with a view to optimizing hydrocarbon recovery from the sludge. TBS samples were contacted with selected solvents blends of varying volumetric ratios, each at a time. The blend generated from xylene, hexane, cyclohexane and petroleum ether representing aliphatic and aromatic interactive combination with varying polarity. Their effects on the oil recovery from tank bottom sludge were determined, with solubility parameter as a factor. The optimum oil recovery by blendA,BandCat room temperature of 29°C, from sample 1 are respectively 54.48% (3:2), 60.33% (2:3) and 61.10% (1:1); from Sample 2, were respectively 66.25% (2:3), 60.80 (3:2) and 63.35 (1:1) at room temperature of 29°C . At room temperature BlendChas the highest performance in extracting oil from sample 1. The highest performance in recovery of oil from sample 2 was observed with blendA(66.25 %.). Solvent extraction process is very effective in recovering hydrocarbons oil from TBS. The use of solvents mixture greatly improved oil recovery from TBS and varies with blend composition and the operating temperature condition.

Characterization of Petroleum Sulfonates

1977 ◽  
Vol 17 (03) ◽  
pp. 184-192 ◽  
Author(s):  
E.I. Sandvik ◽  
W.W. Gale ◽  
M.O. Denekas
Keyword(s):  
Crude Oil ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Aromatic Hydrocarbons ◽  
Primary Component ◽  
Complex Mixtures ◽  
Equivalent Weight ◽  
Recovery Processes ◽  
Weight Distributions

Abstract The majority of surfactant systems considered for enhanced oil recovery include petroleum sulfonates as the primary component. Previous work has shown a marked dependence of petroleum-sulfonate performance upon its composition. petroleum-sulfonate performance upon its composition. Numerous analyses for sulfonate surfactants are described in the literature, but care must be exercised in applying these procedures to oil-recovery agents. In general, published procedures have been developed for sulfonates with relatively narrow equivalent-weight distributions and can cause significant errors when applied to petroleum sulfonates. This paper includes techniques for characterization of laboratory- or plant-manufactured samples as well as samples produced from laboratory core or field tests. Steps described in characterization include separation and purification, gravimetric analysis, colorimetric analysis, determination of average equivalent weight and equivalent-weight distribution, and estimation of relative content of mono-, di-, and polysulfonates. For some analyses, procedures are described to minimize errors caused by changes in composition resulting from preferential separation of sulfonate components in displacement tests. A procedure is described for separation of a manufactured sulfonate into equivalent-weight fractions. These fractions may be recombined in different ratios to examine behavior of sulfonates with various compositions. Analysis of petroleum sulfonates made by different reaction schemes shows that sulfonate composition may be influenced substantially by choice of sulfonation conditions. Introduction Most surfactant-based enhanced oil recovery processes include natural petroleum sulfonates as processes include natural petroleum sulfonates as the primary component. Natural petroleum sulfonates are defined as those manufactured by sulfonation of crude oil, crude distillates, or any portion of these distillates in which hydrocarbons present are not substantially different from their state in the original crude oil. These natural materials, then, are quite different from synthetic sulfonates, which are derived most commonly from sulfonation of olefinic polymers or alkyl aromatic hydrocarbons. In general, polymers or alkyl aromatic hydrocarbons. In general, natural petroleum sulfonates are much more complex mixtures than synthetics. The major reason for this difference in complexity is that the natural materials contain condensed-ring, as well as single-ring, aromatics that permit multiple sulfonation to occur. These di- and polysulfonated materials cause the equivalent-weight distributions of natural sulfonates to be much broader than those of monosulfonated synthetics. It is important to point out that equivalent weight of a material means nothing so far as specific structure is concerned, but it has been shown to be a measure of surfactant effectiveness. Additionally, sulfonate equivalent weight and equivalent-weight distribution, and how they affect and are affected by adsorption, have been explored in detail. Characterization of such complex mixtures is extremely difficult. Standard methods exist that are purported to characterize natural petroleum purported to characterize natural petroleum sulfonates (for example, ASTM Procedures D2548-69, D855-56, D2894-70T, and D1216-70) but these procedures are, for the most part, not suitable for procedures are, for the most part, not suitable for defining surfactants of interest in enhanced oil recovery processes. Brown and Knobloch clearly showed the difficulties in trying to determine molecular species present in natural petroleum sulfonates with broad equivalent-weight spectra. Problems are even more severe when sulfonates Problems are even more severe when sulfonates present in laboratory core effluents or production present in laboratory core effluents or production well samples from field trials are to be characterized. Complications are caused by salt from the aqueous phase as well as crude oil contamination. Salt must be removed scrupulously for accurate equivalent-weight measurements, and crude oil must be removed since it interferes with colorimetric techniques as well as use of light absorbance for concentration determinations. The purpose of this paper is to present several methods for characterizing natural petroleum sulfonates. SPEJ P. 184

Creation of the ‘Internet of things’ in crude oil production

2017 ◽  
Vol 10 ◽  
pp. 120-124
Author(s):  
R.S. Khisamov ◽  
◽  
R.A. Gabdrahmanov ◽  
A.P. Bespalov ◽  
V.V. Zubarev ◽  
...  
Keyword(s):  
Internet Of Things ◽  
Crude Oil ◽  
Oil Production ◽  
The Internet ◽  
Crude Oil Production ◽  
The Internet Of Things
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