Calculation of Crude-Oil Recoveries by Steam Injection

1960 ◽  
Vol 219 (01) ◽  
pp. 251-256
Author(s):  
Bobby L. Landrum ◽  
James E. Smith ◽  
Paul B. Crawford
Keyword(s):  
Crude Oil ◽  
Steam Injection

Correlation of Crude Oil Steam Distillation Yields With Basic Crude Oil Properties

1983 ◽  
Vol 23 (06) ◽  
pp. 937-945 ◽  
Author(s):  
Ching H. Wu ◽  
Robert B. Elder
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Boiling Point ◽  
Steam Distillation ◽  
Recovery Process ◽  
Steam Injection ◽  
Steam Pressure ◽  
Oil Viscosity ◽  
Simulated Distillation ◽  
Distillation Yield

Abstract Steam distillation can occur in reservoirs during steam injection and in-situ combustion processes. To estimate the amount of vaporized oil caused by steam distillation, we established correlations of steam distillation yields with the basic crude oil properties. These correlations were based on steam distillation tests performed on 16 crude oils from various pans of the U.S. The gravity of oils varied from 12 to 40 deg. API [0.99 to 0.83 g/cm3]. The viscosity of oil ranged from 5 to 4,085 cSt [5 to 4085 mm /s] at 100 deg. F [38 deg. C]. The steam distillations were performed at a saturated steam pressure of 220 psia [1.5 MPa]. One oil sample was used in experiments to investigate the effect of steam pressure (220 to 500 psia [1.5 to 3.4 MPa]) on the steam distillation yield. The experiments were carried out to a steam distillation factor (Vw/Voi) of 20, with the factor defined as the cumulative volume of condensed steam used in distillation, Vw, divided by the initial volume of oil, Voi. At a steam distillation factor of 20, the distillation yields ranged from 13 to 57% of the initial oil volume. Several basic crude oil properties can be used to predict steam distillation yields reasonably well. A correlation using oil viscosity in centistokes at 100 deg. F [38 deg. C] can be used to predict the steam distillation yield within a standard error of 4.3 %. The API gravity can be used to estimate wields within 5.6%. A gas chromatographic analysis was made for each crude oil to obtain the component boiling points (simulated distillation temperatures). A correlation parameter was selected from the simulated distillation results that can be used to estimate the steam distillation yields within 4.5%. Introduction Steamflooding has been used commercially to recover heavy oils for several decades. Although it is considered a heavy-oil recovery process, it has been demonstrated to be an effective and commercially feasible process for recovering light oils. To enhance the effectiveness of the oil recovery process, it is important to fully understand and utilize the basic steamflooding mechanisms. Willman et al. investigated the mechanisms of steamflooding. They concluded that oil viscosity reduction, oil volume expansion, and steam distillation are the major mechanisms for oil recovery. Since then, more research has been done on all phases of steam injection. However, steam distillation and its ramifications on recovery have not been quantified fully because of lack of experimental data. Steam distillation can lower the boiling point of a water/oil mixture below the boiling point of the individual components. SPEJ P. 937^

Extra-Heavy Crude Oil Downhole Upgrading Process using Hydrogen Donors under Steam Injection Conditions

2001 ◽  
Author(s):  
Cesar Ovalles ◽  
Carlos Vallejos ◽  
Tito Vasquez ◽  
Jorge Martinis ◽  
Alfredo Perez-Perez ◽  
...  
Keyword(s):  
Crude Oil ◽  
Steam Injection ◽  
Heavy Crude Oil ◽  
Hydrogen Donors ◽  
Heavy Crude

Steam Distillation of Crude Oils

1983 ◽  
Vol 23 (02) ◽  
pp. 265-271 ◽  
Author(s):  
J.H. Duerksen ◽  
L. Hsueh
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Steam Distillation ◽  
Steam Injection ◽  
Hot Water ◽  
Saturated Steam ◽  
Crude Oils ◽  
Simulated Distillation ◽  
Distillation Temperature ◽  
Hydrocarbon Vapor

Abstract The objectives of this investigation were to generate crude oil steam distillation data for the prediction of phase behavior in steamflood simulation and to correlate the steam distillation yields for a variety of crude oils. Thirteen steam distillation tests were run on 10 crude oils ranging in gravity from 9.4 to 37 deg. API (1.004 to 0.840 g/cm3). In each test the crude was steam distilled sequentially at about 220, 300, 400, and 500 deg. F (104, 149, 204, and 260 deg. C). The cumulative steam distillation yields at 400 deg. F (204 deg. C) ranged from about 20 to 55 vol%. Experimental results showed that crude oil steam distillation yields at steamflood conditions are significant, even for heavy oils. The effects of differences in steam volume throughput and steam temperature were taken into account when comparing yields for different crudes or repeat runs on the same crude. Steam distillation yields show a high correlation with crude oil API gravity and wax content. Introduction Steam distillation is an important steamflood oil recovery mechanism, especially in reservoirs containing light oils. Injected steam heats the formation and eventually forms a steam zone, which grows with continued steam injection. A fraction of the crude oil in the steam zone vaporizes into the steam phase according to the vapor pressures of the hydrocarbon constituents contained in the crude oil. The hydrocarbon vapor is transported through the steam zone by the flowing steam. Both the steam and hydrocarbon vapor condense at the steam front to form a hot-water zone and a hydrocarbon distillate bank. The vaporization, transport, and condensation of the hydrocarbon fractions is a dynamic process that displaces the lighter hydrocarbon fractions and generates a distillate bank that miscibly drives reservoir oil to producing wells. The effect of steam distillation on oil recovery has been investigated in several laboratory studies, steamf lood field tests, and in simulation studies. In a critical review of steam flood mechanisms, Wu discussed the steam distillation mechanism in detail. Wu and Brown reported steam distillation yields for six crude oils ranging from 9 to 36 deg. API (1.007 to 0.845 g/cm3). When plotted against their steam distillation correlation parameter, Vw/Voi (the ratio of collected steam condensate, Vw, and initial oil volume, Voi), the yields were independent of the porous medium used, steam-injection rate, and initial oil volume. For the crude oils tested, they concluded that changing the saturated steam pressure and temperature had an insignificant effect on yield, but superheating the steam from 471 to 600 deg. F (244 to 316 deg. C) significantly increased the yield. Wu and Elder reported steam distillation yields for 16 crude oils ranging from 12 to 40 deg. API (0.986 to 0.825 g/cm3). Yields ranged from 12 to 56% of initial oil volume at a distillation temperature and pressure of 380 deg. F and 200 psig (193 deg. C and 1.379 MPa). Yields at Vw/Voi = 15 were correlated with three parameters:simulated distillation temperature of the oil at 20% yield,oil viscosity, andoil API gravity. The simulated distillation obtained by gas chromatography closely approximates the true boiling-point distillation as determined by ASTM distillation. The simulated distillation temperature at 20% yield gave the closest correlation with steam distillation yield. SPEJ P. 265^

Downhole Upgrading of Extra-heavy Crude Oil Using Hydrogen Donors and Methane Under Steam Injection Conditions

2003 ◽  
Vol 21 (1-2) ◽  
pp. 255-274 ◽  
Author(s):  
César Ovalles ◽  
Carlos Vallejos ◽  
Tito Vasquez ◽  
Iraima Rojas ◽  
Ursula Ehrman ◽  
...  
Keyword(s):  
Crude Oil ◽  
Steam Injection ◽  
Heavy Crude Oil ◽  
Hydrogen Donors ◽  
Heavy Crude

IOR/EOR Methods Adapted to High Water Production Zones of Heavy and Extra-Heavy Oil Reservoirs in La Faja Petrolifera Del Orinoco-Venezuela: State of the Art

2021 ◽  
Author(s):  
Fernancelys Rodriguez M.
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
New Technologies ◽  
Research Work ◽  
Steam Injection ◽  
High Water ◽  
Recovery Factor ◽  
Production Methods ◽  
Chemical Eor ◽  
Bodies Of Water

Abstract Venezuela is well known for its immense reserves of heavy and extra heavy crude oils located in La Faja Petrolífera Del Orinoco (La FPO), in the east of the country, with certified reserves of up to 235 billion barrels. The main production methods that have been applied in La FPO are Cold Production with sand through vertical and horizontal wells, and the application of Thermal IOR/EOR methods (e.g. steam injection, In-situ Combustion, SAGD, etc.) and Chemical EOR methods (e.g. polymer flooding). One of the main challenges in La FPO is the increase in the recovery factor (with < 10% of recovery factor to date), due to the low mobility of crude oil at reservoir conditions, and the presence of local and regional bodies of water (flushed zones and aquifers) where conventional cold production methods are not efficient. The presence of these bodies of water negatively affects the production profiles and the quality of crude oil, observing high water cuts due to the adverse mobility ratio and the formation of complex emulsions that affect the crude lifting and separation systems. Due to the current dramatic decline in production of conventional reservoirs in Venezuela and the vital role of La FPO to support Venezuelan oil production, it is important to identify methods and new technologies that allow for the increase in recovery factors in these complex reservoirs. This paper presents a literature review of the applied production methods and those that could be envisaged, including horizontal and dewatering wells as well as reported research work (e.g. Chemical EOR methods), to increase the oil recovery in flushed zones and/or reservoir zones with high water cuts in La FPO.

Laboratory Investigation of the Effect of Solvent Injection on In-Situ Combustion

SPE Journal ◽  
2008 ◽  
Vol 13 (02) ◽  
pp. 153-163 ◽  
Author(s):  
Jean Cristofari ◽  
Louis M. Castanier ◽  
Anthony R. Kovscek
Keyword(s):  
Crude Oil ◽  
Oil Production ◽  
Steam Injection ◽  
Northern Coast ◽  
Oil Viscosity ◽  
In Situ Combustion ◽  
Solvent Injection ◽  
Effect Of Solvent ◽  
Viscous Oil

Summary Application of cyclic solvent injection into heavy and viscous crude oil followed by in-situ combustion of heavy residues is explored from a laboratory perspective. The solvent reduces oil viscosity in-situ and extracts the lighter crude-oil fractions. Combustion cleans the near-well region and stimulates thermally the oil production. Both solvent injection and in-situ combustion are technically effective. The combination of the two methods, however, has never been tried to our knowledge. Hamaca (Venezuela) and West Sak (Alaska) crude oils were employed. First, ramped temperature oxidation studies were conducted to measure the kinetic properties of the oil prior to and following solvent injection. Pentane, decane, and kerosene were the solvents of interest. Second, solvent was injected in a cyclic fashion into a 1-m-long combustion tube. Then, the tube was combusted. Hamaca oil presented good burning properties, especially following pentane injection. The pentane extracted lighter components of the crude and deposited preferentially effective fuel for combustion. On the other hand, West Sak oil did not exhibit stable combustion properties without solvent injection, following solvent injection, and even when metallic additives were added to enhance the combustion. We were unable to propagate a burning front within the combustion tube. Nevertheless, the experimental results do show that this combined solvent combustion method is applicable to the broad range of oil reservoirs with properties similar to Hamaca. Introduction This article investigates the effect of solvent injection on the subsequent performance of in-situ combustion. The work is based on experimental results obtained by a combination of these two successful in-situ upgrading processes for viscous oils. It is envisioned that application in the field occurs first by a cycle of solvent injection, a short soak period, and subsequent oil production using the same well (Castanier and Kovscek 2005). By mixing with oil, the solvent decreases the oil viscosity and upgrades the crude by extracting in-situ the lighter ends of the crude oil. The heavy ends, that are markedly less interesting, are left behind. Injection of solvent and oil production occurs for a number of cycles until the economic limit is reached or until the deposition of crude oil heavy ends damages production. The solvent injection phase is followed by in-situ combustion that burns the heavy ends left from the solvent injection. By switching from air to nitrogen injection, the combustion is extinguished. Again, oil is produced by the same well used for injection in a cyclic fashion. Combustion enhances the production by decreasing thermally the oil viscosity and adding energy to the reservoir through the formation of combustion gases. The combustion also upgrades the oil through thermal cracking (Castanier and Brigham 2003). For our experiments, two oils of particular interest were used. The first experiments employed crude oil from Hamaca (Venezuela), where the field location requires important costs of transporting crude to upgrading facilities. The second set of experiments was conducted with viscous West Sak oil (Alaska), where steam injection currently appears to be unsuitable because of heat losses to permafrost. While the presence of oil in the Orinoco heavy-oil belt, in Central Venezuela, was discovered in the 1930s, the first rigorous evaluation of the resources was made in the 1980s, and the region was divided into four areas: Machete, Zuata, Hamaca, and Cerro Negro. It contains between 1.2 and 1.8 trillion recoverable barrels (Kuhlman 2000) of heavy and extra-heavy oil. The 9-11° API density crude is processed at the Jose refinery complex on the northern coast of Venezuela. The cost of transporting heavy oils to the northern coast provides an incentive to investigate in-situ upgrading. In 2003, the total production from these projects was about 500,000 B/D of synthetic crude oil. This figure was expected to increase to 600,000 B/D by 2005 (Acharya et al. 2004). West Sak is a viscous oil reservoir located within the Kuparuk River Unit on the North Slope of Alaska. It is part of a larger viscous oil belt that includes Prudhoe Bay. The estimated total oil in place ranges from 7 to 9 billion barrels, with an oil gravity ranging from 10 to 22°API. The reservoir depth ranges from 2,500 to 4,500 feet, with gross thickness of 500 feet and an average net thickness of 90 feet. The temperature is between 45 and 100°F, and there is a 2,000-ft (600-m) -thick Permafrost layer. In March 2005, 16,000 BOPD were produced and 40,000 BOPD are planned for 2007 (Targac et al. 2005). Within the scope of this study, West Sak is of particular interest because there are technical difficulties with steam injection that include (Gondouin and Fox 1991):Surface-generated steam passing through a thick permafrost layer; the well would sink if the permafrost melted.The reservoirs consist of thin, medium-permeability layers.The formation may contain swelling clays that reduce the rock permeability when exposed to steam condensate. Solvent injection and in-situ combustion are effective in a variety of fields. Both techniques upgrade the oil directly in the reservoir, thereby making heavy resources easier to exploit. The combination of these two processes is applicable at large scale to recover viscous oil, or in-situ combustion could be applied on an ad hoc basis to clean the wellbore region, increase the permeability, and thus act as a stimulation process.

scholarly journals Improvement of Steam Injection Processes Through Nanotechnology: An Approach through in Situ Upgrading and Foam Injection

Energies ◽  
2019 ◽  
Vol 12 (24) ◽  
pp. 4633 ◽  
Author(s):  
Oscar E. Medina ◽  
Yira Hurtado ◽  
Cristina Caro-Velez ◽  
Farid B. Cortés ◽  
Masoud Riazi ◽  
...  
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
High Performance ◽  
Steam Injection ◽  
American Petroleum Institute ◽  
Oil Viscosity ◽  
Nitrogen Injection ◽  
Injection Process ◽  
Reservoir Conditions

This study aims to evaluate a high-performance nanocatalyst for upgrading of extra-heavy crude oil recovery and at the same time evaluate the capacity of foams generated with a nanofluid to improve the sweeping efficiency through a continuous steam injection process at reservoir conditions. CeO2±δ nanoparticles functionalized with mass fractions of 0.89% and 1.1% of NiO and PdO, respectively, were employed to assist the technology and achieve the oil upgrading. In addition, silica nanoparticles grafted with a mass fraction of 12% polyethylene glycol were used as an additive to improve the stability of an alpha-olefin sulphonate-based foam. The nanofluid formulation for the in situ upgrading process was carried out through thermogravimetric analysis and measurements of zeta potential during eight days to find the best concentration of nanoparticles and surfactant, respectively. The displacement test was carried out in different stages, including, (i) basic characterization, (ii) steam injection in the absence of nanofluids, (iii) steam injection after soaking with nanofluid for in situ upgrading, (iv) N2 injection, and (v) steam injection after foaming nanofluid. Increase in the oil recovery of 8.8%, 3%, and 5.5% are obtained for the technology assisted by the nanocatalyst-based nanofluid, after the nitrogen injection, and subsequent to the thermal foam injection, respectively. Analytical methods showed that the oil viscosity was reduced 79%, 77%, and 31%, in each case. Regarding the asphaltene content, with the presence of the nanocatalyst, it decreased from 28.7% up to 12.9%. Also, the American Petroleum Institute (API) gravity values increased by up to 47%. It was observed that the crude oil produced after the foam injection was of higher quality than the crude oil without treatment, indicating that the thermal foam leads to a better swept of the porous medium containing upgraded oil.

scholarly journals Screening of waterflooding, hot waterflooding and steam injection for extra heavy crude oil production from Tatarstan oilfield

2021 ◽  
Vol 931 (1) ◽  
pp. 012002
Author(s):  
A Pituganova ◽  
I Minkhanov ◽  
A Bolotov ◽  
M Varfolomeev
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
Water Injection ◽  
Oil Production ◽  
Steam Injection ◽  
Hot Water ◽  
Heavy Crude Oil ◽  
Oil Viscosity ◽  
Heavy Crude ◽  
Bulk Model

Abstract Thermal enhanced oil recovery techniques, especially steam injection, are the most successful techniques for extra heavy crude oil reservoirs. Steam injection and its variations are based on the decrease in oil viscosity with increasing temperature. The main objective of this study is the development of advanced methods for the production of extra heavy crude oil in the oilfield of the Republic of Tatarstan. The filtration experiment was carried out on a bulk model of non-extracted core under reservoir conditions. The experiment involves the injection of slugs of fresh water, hot water and steam. At the stage of water injection, no oil production was observed while during steam injection recovery factor (RF) achieved 13.4 % indicating that fraction of immobile oil and non-vaporizing residual components is high and needed to be recovered by steam assisted EORs.

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