Log in

Relevant bibliographies by topics / Oil reservoir engineering

Contents

Journal articles
Dissertations / Theses
Books
Book chapters
Conference papers
Reports

Academic literature on the topic 'Oil reservoir engineering'

Author: Grafiati

Published: 4 June 2021

Last updated: 30 July 2024

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'Oil reservoir engineering.'

Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.

You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.

Journal articles on the topic "Oil reservoir engineering"

1

Cui, Guodong, Zheng Niu, Zhe Hu, Xueshi Feng, and Zehao Chen. "The Production Analysis and Exploitation Scheme Design of a Special Offshore Heavy Oil Reservoir—First Offshore Artificial Island with Thermal Recovery." Journal of Marine Science and Engineering 12, no. 7 (July 15, 2024): 1186. http://dx.doi.org/10.3390/jmse12071186.

Full text

Abstract:

More and more offshore heavy oil resources are discovered and exploited as the focus of the oil and gas industry shifts from land to sea. However, unlike onshore heavy oil reservoirs, offshore heavy oil reservoirs not only have active edge and bottom water but also have different exploitation methods. In this paper, a typical special heavy oil reservoir in China was analyzed in detail, based on geology–reservoir–engineering integration technology. Firstly, it is identified as a self-sealing bottom water heavy oil reservoir by analyzing its geological characteristics and hydrocarbon accumulation mechanism. Secondly, the water cut is initially controlled by oil viscosity, but subsequently, by reservoir thickness through the analysis of oil and water production data. Thirdly, the bottom oil–water contact of the reservoir was re-corrected to build an accurate 3D geological model, based on the production history matching of a single well and the whole reservoir. Lastly, a scheme of thermal production coupled with cold production was proposed to exploit this special reservoir, and the parameters of steam, N2, and CO2 injection and production were optimized to predict oil production. This work can provide a valuable development model for the efficient exploitation of similar offshore special heavy oil reservoirs.

APA, Harvard, Vancouver, ISO, and other styles

2

Amer, Manar M., and Dahlia A. Al-Obaidi. "Methods Used to Estimate Reservoir Pressure Performance: A Review." Journal of Engineering 30, no. 06 (June 1, 2024): 83–107. http://dx.doi.org/10.31026/j.eng.2024.06.06.

Full text

Abstract:

Reservoir pressure plays a significant role in all reservoir and production engineering studies. It is crucial to characterize petroleum reservoirs: by detecting fluid movement, computing oil in place, and calculating the recovery factor. Knowledge of reservoir pressure is essential for predicting future production rates, optimizing well performance, or planning enhanced oil recovery strategies. However, applying the methods to investigate reservoir pressure performance is challenging because reservoirs are large, complex systems with irregular geometries in subsurface formations with numerous uncertainties and limited information about the reservoir's structure and behavior. Furthermore, many computational techniques, both numerical and analytical, have been utilized to examine reservoir pressure performance. This paper summarizes the concepts and applications of traditional and novel ways to investigate reservoir pressure changes over time. It provides a comprehensive review that assists the reader in recognizing and distinguishing between various techniques for obtaining an accurate description of reservoir pressure behavior during production, such as the reservoir simulation method, material balance equation approach, time-lapse seismic data, and modern artificial intelligence methods. Thus, the central concept of these procedures and a list of the authors' research are discussed.

APA, Harvard, Vancouver, ISO, and other styles

3

Hoffman, Monty, and James Crafton. "Multiphase flow in oil and gas reservoirs." Mountain Geologist 54, no. 1 (January 2017): 5–14. http://dx.doi.org/10.31582/rmag.mg.54.1.5.

Full text

Abstract:

The porous rocks that make up oil and gas reservoirs are composed of complex combinations of pores, pore throats, and fractures. Pore networks are groups of these void spaces that are connected by pathways that have the same fluid entry pressures. Any fluid movement in pore networks will be along the pathways that require the minimum energy expenditure. After emplacement of hydrocarbons in a reservoir, fluid saturations, capillary pressure, and energy are in equilibrium, a significant amount of the reservoir energy is stored at the interface between the fluids. Any mechanism that changes the pressure, volume, chemistry, or temperature of the fluids in the reservoir results in a state of energy non-equilibrium. Existing reservoir engineering equations do not address this non-equilibrium condition, but rather assume that all reservoirs are in equilibrium. The assumption of equilibrium results in incorrect descriptions of fluid flow in energy non-equilibrium reservoirs. This, coupled with the fact that drilling-induced permeability damage is common in these reservoirs, often results in incorrect conclusions regarding the potential producibility of the well. Relative permeability damage, damage that can change which fluids are produced from a hydrocarbon reservoir, can occur even in very permeable reservoirs. Use of dependent variables in reservoir analysis does not correctly describe the physics of fluid flow in the reservoir and will lead to potentially incorrect answers regarding producibility of the reservoir.

APA, Harvard, Vancouver, ISO, and other styles

4

Taggart, I. J., and H. A. Salisch. "FRACTAL GEOMETRY, RESERVOIR CHARACTERISATION AND OIL RECOVERY." APPEA Journal 31, no. 1 (1991): 377. http://dx.doi.org/10.1071/aj90030.

Full text

Abstract:

Reservoir heterogeneity is a dominant factor in determining large-scale fluid flow behaviour in reservoirs. Engineering estimates of oil production rates need to acknowledge and incorporate the effect of such heterogeneities. This work examines the use of fractal-based scaling techniques aimed at characterising heterogeneous reservoirs for simulation purposes. Well log data provide suitable fine-scale information for estimating the fractal dimension of reservoirs as well as providing known end- point data for interwell property value interpolation. Fractal techniques allow this interpolation to be performed in a manner which reproduces the same correlation structure as that found in the original well logs. Conditional simulation in these property fields allows the interaction between reservoir heterogeneity and fluid flow to be studied on a range of scales up to the interwell spacing. Analysis of results allows the calculation of effective reservoir properties which characterise the reservoir in terms of large-scale performance.

APA, Harvard, Vancouver, ISO, and other styles

5

Pierpont, Rob, Kristoffer Birkeland, Alexandra Cely, Tao Yang, Li Chen, Vladislav Achourov, Soraya S. Betancourt, et al. "Enigmatic Reservoir Properties Deciphered Using Petroleum System Modeling and Reservoir Fluid Geodynamics." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 64, no. 1 (February 1, 2023): 6–17. http://dx.doi.org/10.30632/pjv64n1-2023a1.

Full text

Abstract:

Two adjacent reservoirs in offshore oil fields have been evaluated using extensive data acquisition across multiple disciplines; several surprising observations were made. Differing levels of biodegradation were measured in the nearly adjacent reservoirs, yet related standard geochemical markers are contradictory. Unexpectedly, the more biodegraded oil had less asphaltene content, and this reservoir had some heavy end deposition in the core but upstructure, not at the oil-water contact (OWC) as would be expected, especially with biodegradation. Wax appears to be an issue in the nonbiodegraded oil. These many puzzling observations, along with unclear connectivity, gave rise to uncertainties about field development planning. Combined petroleum systems and reservoir fluid geodynamic considerations resolved the observations into a single, self-consistent geo-scenario, the co-evolution of reservoir rock and fluids in geologic time. A spill-fill sequence of trap filling with biodegradation helps explain differences in biodegradation and wax content. A subsequent, recent charge of condensate, stacked in one fault block and mixed in the target oil reservoir in the second fault block, explains conflicting metrics of biodegradation between C7 vs. C16 indices. Asphaltene instability and deposition at the upstructure contact between the condensate and black oil, and the motion of this contact during condensate charge, explain heavy end deposition in core. Moreover, this process accounts for asphaltene dilution and depletion in the corresponding oil. Downhole fluid analysis (DFA) asphaltene gradients and variations in geochemical markers with seismic imaging clarify likely connectivity in these reservoirs. The geo-scenario provides a benchmark of comparison for all types of reservoir data and readily projects into production concerns. The initial apparent puzzles of this oil field have been resolved with a robust understanding of the corresponding reservoirs and development strategies.

APA, Harvard, Vancouver, ISO, and other styles

6

Carpenter, Chris. "Study Reviews Technologies, Work Flows in Heavy Oil Reservoir Management." Journal of Petroleum Technology 75, no. 04 (April 1, 2023): 79–81. http://dx.doi.org/10.2118/0423-0079-jpt.

Full text

Abstract:

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 209328, “Heavy Oil Reservoir Management—Latest Technologies and Work Flows,” by Hakki Aydin, SPE, Middle East Technical University; Nirup Nagabandi, Incendium Technologies; and Cenk Temizel, SPE, Saudi Aramco, et al. The paper has not been peer reviewed. _ Successful heavy oil reservoir management practices are built on analyzing and accurately predicting reservoir behavior over time. Given the complex nature of heavy oil reservoirs, including geomechanical properties and fluid-flow behavior, a need exists to develop a repeatable technique that can account for these complexities within an acceptable margin of accuracy. The objective of the complete paper is to conduct a comprehensive review of recent technologies and work flows developed for heavy oil reservoir management that can be used as a single source of reference for the industry. Introduction Because of its comprehensive nature, much of the complete paper is dedicated to a review of the characteristics of heavy oil reservoirs and their exploitation, including thermal and nonthermal methods and the literature dedicated thereto. This synopsis will concentrate on the authors’ reviews of work flows to manage these reservoirs and field applications of the methodologies they review. Work Flow for Heavy Oil Reservoir Management Reservoir management is a multidisciplinary field involving detailed analysis of geosciences such as reservoir engineering, geological engineering, and petrophysics. Evaluation of geological information and fluid properties helps to understand the distribution of heavy oil in the reservoir. Understanding the characteristics of heavy oil reservoirs is essential for selecting the appropriate enhanced oil recovery (EOR) method. Reservoir-surveillance techniques play a critical role in understanding complex systems. Statistical approaches might be required to handle extensive data sets of production history and petrophysical data. The main goal of the reservoir management team in thermal EOR methods is to optimize parameters in steam-injection projects to maximize recovery rates from heavy oil reservoirs. The important parameters influencing the success of thermal projects include injection rates and pressures, preferential steam paths, well profiles, and reservoir depth. Previous work has presented a work flow for optimizing steamfloods in Oman. The work flow involves a review of production and injection history, petrophysical properties, and geological descriptions. Steam/oil ratio was used as a key performance indicator for steam management; it is defined as barrels of steam injected for 1 bbl of additional oil production. The steam breakthrough was monitored from the wellhead flowing temperature of the producer wells. A sudden increase in wellhead temperature is associated with a steam breakthrough. The permeability map of the reservoir helps to select appropriate injectors for a steamflood. High-permeability wells might lead to fingering, causing less recovery. Vertical conformance is desired to achieve oil sweep with steam. Observation wells are the controlling stations of steamflooding efficiency. It is critical to place the observation wells in heterogeneous reservoirs. Geophysical methods also are applied for surveillance of steam-injection projects. Real-time surveillance plays a critical role in the optimization of heavy oil reservoirs. The authors describe a modeling technique called Production Universe (PU) that enables operators to estimate oil and water production in real time. PU is effective at finding the offending well in case of sudden changes in field-level production. PU provides an automated daily production and deferment report that guides analysts to identify low-efficiency wells for remedial operations.

APA, Harvard, Vancouver, ISO, and other styles

7

Xia, Zhizeng, Xuewu Wang, Rui Xu, and Weiwei Ren. "Tight oil reservoir production characteristics developed by CO2 huff ‘n’ puff under well pattern conditions." Journal of Petroleum Exploration and Production Technology 12, no. 2 (January 9, 2022): 473–84. http://dx.doi.org/10.1007/s13202-021-01446-1.

Full text

Abstract:

AbstractTight oil reservoirs have poor physical properties, and the problems including rapid oil rate decline and low oil recovery degree are quite common after volume fracturing. To obtain a general understanding of tight oil reservoir production improvement by CO2 huff ‘n’ puff, the high-pressure physical properties of typical tight oil samples are measured. Combining the typical reservoir parameters, the production characteristics of the tight oil reservoir developed by the CO2 huff ‘n’ puff are numerically studied on the basis of highly fitted experimental results. The results show that: (1) during the natural depletion stage, the oil production rate decreases rapidly and the oil recovery degree is low because of the decrease in oil displacement energy and the increase in fluid seepage resistance. (2) CO2 huff ‘n’ puff can improve the development effect of tight oil reservoirs by supplementing reservoir energy and improving oil mobility, but the development effect gradually worsens with increasing cycle number. (3) The earlier the CO2 injection timing is, the better the development effect of the tight reservoir is, but the less sufficient natural energy utilization is. When carrying out CO2 stimulation, full use should be made of the natural energy, and the appropriate injection timing should be determined by comprehensively considering the formation-saturation pressure difference and oil production rate. The research results are helpful for strengthening the understanding of the production characteristics of tight oil reservoirs developed by CO2 huff ‘n’ puff.

APA, Harvard, Vancouver, ISO, and other styles

8

Cheng, Hong. "The Enhanced Oil Recovery Effect of Nitrogen-Assisted Gravity Drainage in Karst Reservoirs with Different Genesis: A Case Study of the Tahe Oilfield." Processes 11, no. 8 (August 2, 2023): 2316. http://dx.doi.org/10.3390/pr11082316.

Full text

Abstract:

For the Tahe Oilfield, there are multiple sets of karst reservoirs with different genesis developed in carbonate fracture-vuggy reservoirs and the varying karst reservoir type has a considerable influence on the distribution of residual oil. The complex characteristics of different karst reservoirs and the difficulty in producing the remaining oil in the middle and lower part of the reservoir greatly restrict the recovery effects. This work managed to comprehensively investigate the action mechanism of nitrogen-assisted gravity drainage (NAGD) on remaining oil in reservoirs with different karst genesis through modeling and experiments. Based on geological characteristics and modeling results, a reservoir-profile model considering reservoir type, fracture distribution, and the fracture–cave combination was established, the displacement experiments of main reservoirs such as the epikarst zone, underground river, and fault karst were carried out, and the oil–gas–water multiphase flow was visually analyzed. The remaining oil state before and after NAGD was studied, and the difference in recovery enhancement in different genetic karst reservoirs was quantitatively compared. The results show that NAGD was helpful in enhancing oil recovery (EOR) for reservoirs with different karst genesis. NAGD technique has the greatest increasing effect on the sweep efficiency of the fault-karst reservoir, followed by the epikarst zone reservoir, and the smallest in the underground river reservoir. The results of this research will facilitate an understanding of the EOR effect of karst-reservoir types on NAGD and provide theory and technical support for the high-efficiency development in varying karst reservoirs in the Tahe Oilfield.

APA, Harvard, Vancouver, ISO, and other styles

9

Li, Bing, and Lei Zhao. "Water Injection Proposal for Block 5 Oilfield to Increase Oil Reserves." Advanced Materials Research 1073-1076 (December 2014): 2316–20. http://dx.doi.org/10.4028/www.scientific.net/amr.1073-1076.2316.

Full text

Abstract:

This article revises the low pressure reservoir Block 5 controlled by structure trap located in South China Sea and analyses the current situations of the reservoir including G&G and reservoir engineering. The results indicate that down-dip wells already located in the water which was original oil based on new study and now could be converted to injector to increase oil reserves. Finally according to the study, the same method can be used in the similar reservoirs.

APA, Harvard, Vancouver, ISO, and other styles

10

Zhang, Lei, and Guo Ming Liu. "Analysis Development Status of A12 Reservoir." Advanced Materials Research 650 (January 2013): 664–66. http://dx.doi.org/10.4028/www.scientific.net/amr.650.664.

Full text

Abstract:

A12 oil and gas reservoirs in L Oilfield Carboniferous carbonate rocks of oil and gas bearing system, saturated with the gas cap and edge water and bottom water reservoir. The A12 oil and gas reservoir structure the relief of the dome-shaped anticline, oil, gas and water distribution controlled by structure, the gas interface -2785 meters above sea level, the oil-water interface altitude range -2940 ~-2980m, average-2960m. Average reservoir thickness of 23m, with a certain amount of dissolved gas drive and gas cap gas drive energy, but not very active edge and bottom water, gas cap drive index.

APA, Harvard, Vancouver, ISO, and other styles

More sources

Dissertations / Theses on the topic "Oil reservoir engineering"

1

Sagar, Rajiv K. "Reservoir description by integration of well test data and spatial statistics /." Access abstract and link to full text, 1993. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9416603.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Duruewuru, Anthony U. "Thermodynamic analysis of transient two-phase flow in oil and gas reservoirs /." Full-text version available from OU Domain via ProQuest Digital Dissertations, 1985.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

3

Wang, Linna. "Reservoir simulation study for the South Slattery Field." Laramie, Wyo. : University of Wyoming, 2007. http://proquest.umi.com/pqdweb?did=1400965521&sid=1&Fmt=2&clientId=18949&RQT=309&VName=PQD.

Full text

APA, Harvard, Vancouver, ISO, and other styles

4

Jafarpour, Behnam. "Oil reservoir characterization using ensemble data assimilation." Thesis, Massachusetts Institute of Technology, 2008. http://hdl.handle.net/1721.1/43046.

Full text

Abstract:

Thesis (Ph. D.)--Massachusetts Institute of Technology, Dept. of Civil and Environmental Engineering, 2008.
Pages 211-212 blank.
Includes bibliographical references.
Increasing world energy demand combined with decreasing discoveries of new and accessible hydrocarbon reserves are necessitating optimal recovery from the world's current hydrocarbon resources. Advances in drilling and monitoring technologies have introduced intelligent oilfields that provide real-time measurements of reservoir conditions. These measurements can be used for more frequent reservoir model calibration and characterization that can lead to improved oil recovery though model-based closed-loop control and management. This thesis proposes an efficient method for probabilistic characterization of reservoir states and properties. The proposed algorithm uses an ensemble data assimilation approach to provide stochastic characterization of reservoir attributes by conditioning individual prior ensemble members on dynamic production observations at wells. The conditioning is based on the second-order Kalman filter analysis and is performed recursively, which is suitable for real-time control applications. The prior sample mean and covariance are derived from nonlinear dynamic propagation of an initial ensemble of reservoir properties. Realistic generation of these initial reservoir properties is shown to be critical for successful performance of the filter. When properly designed and implemented, recursive ensemble filtering is concluded to be a practical and attractive alternative to classical iterative history matching algorithms. A reduced representation of reservoir's states and parameters using discrete cosine transform is presented to improve the estimation problem and geological consistency of the results. The discrete cosine transform allows for efficient, flexible, and robust parameterization of reservoir properties and can be used to eliminate redundancy in reservoir description while preserving important geological features.
This improves under-constrained inverse problems such as reservoir history matching in which the number of unknowns significantly exceeds available data. The proposed parameterization approach is general and can be applied with any inversion algorithm. The suitability of the proposed estimation framework for hydrocarbon reservoir characterization is demonstrated through several water flooding examples using synthetic reservoir models.
by Behnam Jafarpour.
Ph.D.

APA, Harvard, Vancouver, ISO, and other styles

5

Xiao, Jinjiang. "Wellbore effects on pressure transient analysis /." Access abstract and link to full text, 1993. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9325433.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

Tie, Hongguang. "Oil recovery by spontaneous imbibition and viscous displacement from mixed-wet carbonates." Laramie, Wyo. : University of Wyoming, 2006. http://proquest.umi.com/pqdweb?did=1212796311&sid=1&Fmt=2&clientId=18949&RQT=309&VName=PQD.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Aasum, Yngve. "Effective properties of reservoir simulator grid blocks /." Access abstract and link to full text, 1992. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9300177.

Full text

APA, Harvard, Vancouver, ISO, and other styles

8

Aljuhani, Salem Gulaiyel. "Data integration for reservoir characterization : a central Arabian oil field /." Digital version accessible at:, 1999. http://wwwlib.umi.com/cr/utexas/main.

Full text

APA, Harvard, Vancouver, ISO, and other styles

9

Nunsavathu, Upender Naik. "Productivity index of multilateral wells." Morgantown, W. Va. : [West Virginia University Libraries], 2006. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4702.

Full text

Abstract:

Thesis (M.S.)--West Virginia University, 2006.
Title from document title page. Document formatted into pages; contains xi, 106 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 104-106).

APA, Harvard, Vancouver, ISO, and other styles

10

Gessel, Gregory M. "A New Method for Treating Wells in Reservoir Simulation." Diss., CLICK HERE for online access, 2007. http://contentdm.lib.byu.edu/ETD/image/etd1902.pdf.

Full text

APA, Harvard, Vancouver, ISO, and other styles

More sources

Books on the topic "Oil reservoir engineering"

1

Lyons, William C. Working guide to reservoir engineering. Amsterdam: Gulf Pub./Elsevier, 2010.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

2

Ahmed, Tarek H. Reservoir engineering handbook. Houston, Tex: Gulf Pub. Co., 2000.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

3

Ahmed, Tarek H. Reservoir engineering handbook. Houston, Tex: Gulf Pub. Co, 2000.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

4

Ahmed, Tarek H. Reservoir engineering handbook. Houston, Tex: Gulf Pub. Co., 2000.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

5

Chilingar, George V. Carbonate reservoir characterization: A geologic-engineering analysis. Edited by Mazzullo S. J, Rieke Herman H, Dominguez G. C, Samaniego V. F, Cinco-L. Heber, and Knovel (Firm). Amsterdam: Elsevier, 1996.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

6

Sydansk, Robert D. Reservoir conformance improvement. Richardson, TX: Society of Petroleum Engineers, 2011.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

7

Ezekwe, Nnaemeka. Petroleum reservoir engineering practice. Upper Saddle River, NJ: Prentice Hall, 2011.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

8

Craig, Forrest F. The reservoir engineering aspects of waterflooding. Richardson, Tex: Henry L. Doherty Memorial Fund of AIME, 1993.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

9

Craig, Forrest F. The reservoir engineering aspects of waterflooding. Richardson, Tex: Henry L. Doherty Memorial Fund of AIME, 1993.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

10

C, Mattax Calvin, and Dalton Robert L, eds. Reservoir simulation. Richardson, TX: Henry L. Doherty Memorial Fund of AIME, Society of Petroleum Engineers, 1990.

Find full text

APA, Harvard, Vancouver, ISO, and other styles

More sources

Book chapters on the topic "Oil reservoir engineering"

1

Warren, Quinta Nwanosike. "Reservoir Engineering." In Oil and Gas Engineering for Non-Engineers, 25–44. Boca Raton: CRC Press, 2022. http://dx.doi.org/10.1201/9781003100461-3.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Pandey, Yogendra Narayan, Ayush Rastogi, Sribharath Kainkaryam, Srimoyee Bhattacharya, and Luigi Saputelli. "Reservoir Engineering." In Machine Learning in the Oil and Gas Industry, 195–222. Berkeley, CA: Apress, 2020. http://dx.doi.org/10.1007/978-1-4842-6094-4_6.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Lake, Larry W. "A Marriage of Geology and Reservoir Engineering." In Numerical Simulation in Oil Recovery, 177–98. New York, NY: Springer US, 1988. http://dx.doi.org/10.1007/978-1-4684-6352-1_13.

Full text

APA, Harvard, Vancouver, ISO, and other styles

4

Allen, Myron B. "Basic Mechanics of Oil Reservoir Flows." In Lecture Notes in Engineering, 1–86. New York, NY: Springer US, 1988. http://dx.doi.org/10.1007/978-1-4613-9598-0_1.

Full text

APA, Harvard, Vancouver, ISO, and other styles

5

Chierici, Gian Luigi. "Techniques for Improving the Oil Recovery." In Principles of Petroleum Reservoir Engineering, 255–375. Berlin, Heidelberg: Springer Berlin Heidelberg, 1995. http://dx.doi.org/10.1007/978-3-642-78243-5_5.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

Chierici, Gian Luigi. "The Evaluation of Oil and Gas Reserves." In Principles of Petroleum Reservoir Engineering, 117–38. Berlin, Heidelberg: Springer Berlin Heidelberg, 1994. http://dx.doi.org/10.1007/978-3-662-02964-0_4.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Chierici, Gian Luigi. "The Interpretation of Production Tests in Oil Wells." In Principles of Petroleum Reservoir Engineering, 167–231. Berlin, Heidelberg: Springer Berlin Heidelberg, 1994. http://dx.doi.org/10.1007/978-3-662-02964-0_6.

Full text

APA, Harvard, Vancouver, ISO, and other styles

8

Sinha, Mihir K., and Larry R. Padgett. "Oil in Place and Recoverable Reserve by the Volumetric Method." In Reservoir Engineering Techniques Using Fortran, 31–40. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-009-5293-5_4.

Full text

APA, Harvard, Vancouver, ISO, and other styles

9

Sinha, Mihir K., and Larry R. Padgett. "In Situ Combustion Performance Using the Oil-Displaced/Volume-Burned Method." In Reservoir Engineering Techniques Using Fortran, 127–33. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-009-5293-5_12.

Full text

APA, Harvard, Vancouver, ISO, and other styles

10

Sinha, Mihir K., and Larry R. Padgett. "Prediction of Performance and Ultimate Oil Recovery of a Combination Solution Gas/Gas-Cap Drive Reservoir." In Reservoir Engineering Techniques Using Fortran, 81–96. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-009-5293-5_9.

Full text

APA, Harvard, Vancouver, ISO, and other styles

Conference papers on the topic "Oil reservoir engineering"

1

Mitwalli, Magdi, and Ali Singab. "Reservoir Engineering Experience in Horizontal Wells." In Middle East Oil Show. Society of Petroleum Engineers, 1991. http://dx.doi.org/10.2118/21341-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Sener, I., and C. S. Bakiler. "Basic Reservoir Engineering and History-Match Study on the Fractured Raman Reservoir, Turkey." In Middle East Oil Show. Society of Petroleum Engineers, 1989. http://dx.doi.org/10.2118/17955-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Thakur, Ganesh C. "Heavy Oil Reservoir Management." In Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 1997. http://dx.doi.org/10.2118/39233-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

4

Okasha, Taha, Mohammed Al Hamad, Bastian Sauerer, and Wael Abdallah. "Accurate Live Interfacial Tension for Improved Reservoir Engineering Practices." In SPE Middle East Oil & Gas Show and Conference. SPE, 2021. http://dx.doi.org/10.2118/204615-ms.

Full text

Abstract:

Abstract Current reservoir simulators use interfacial tension (IFT) values derived from dead oil measurements at ambient conditions or predicted from literature correlations. IFT is highly dependent on temperature, pressure and fluid composition. Therefore, knowledge of the IFT value at reservoir conditions is essential for accurate reservoir fluid characterization. This study compares IFT values from dead and live oil measurements and the results of literature predicted values, thereby clearly showing the weakness of existing correlations when trying to predict crude oil IFT. A total of ten live oils was sampled for this study. Using the pendent drop technique, IFT was measured for each oil at different conditions: in the under-saturated region at reservoir pressure and temperature, in the saturated region at reservoir temperature, and for dead oil at ambient conditions. Basic PVT properties such as gas to oil ratio (GOR), gas and liquid composition, density, viscosity and molecular weight were also measured. The bubble point for each oil was identified to define the pressure step in the saturated region for extra IFT measurement. The equilibrium IFT values for the live oils were generally higher than for the corresponding dead oils. For oils where this general trend was not observed, contaminations were found in the crude samples. The use of current literature correlations does not allow to predict correct reservoir IFT. Therefore, this study provides accurate live IFT values for a variety of reservoir fluids and conditions in combination with live oil properties, highly beneficial to reservoir engineers, allowing better oil production planning.

APA, Harvard, Vancouver, ISO, and other styles

5

Evans, P., and K. Robinson. "Produced Water Management - Reservoir and Facilities Engineering Aspects." In Middle East Oil Show and Conference. Society of Petroleum Engineers, 1999. http://dx.doi.org/10.2118/53254-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

Gurgel, Antonio Robson, Jennys Lourdes Meneses Barillas, Marcos Allyson Felipe Rodrigues, Tarcilio Viana Dutra, and Wilson da Mata. "Reservoir and Operational Analysis for Steamflooding on Thin Oil Reservoirs." In Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/122067-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Huan, Guanren. "The Black Oil Model For A Heavy Oil Reservoir." In International Meeting on Petroleum Engineering. Society of Petroleum Engineers, 1986. http://dx.doi.org/10.2118/14853-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

8

Li, Xiang. "Gold Oil Field Reservoir Characteristics." In 2015 International Conference on Environmental Engineering and Remote Sensing. Paris, France: Atlantis Press, 2015. http://dx.doi.org/10.2991/eers-15.2015.13.

Full text

APA, Harvard, Vancouver, ISO, and other styles

9

Hunt, James L., and M. Y. Soliman. "Reservoir Engineering Aspects of Fracturing High Permeability Formations." In SPE Asia Pacific Oil and Gas Conference. Society of Petroleum Engineers, 1994. http://dx.doi.org/10.2118/28803-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

10

Naugolnov, Mikhail, and Rustam Murtazin. "Reservoir Value-Engineering for West Siberian Oil Fields." In SPE Annual Caspian Technical Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/198374-ms.

Full text

APA, Harvard, Vancouver, ISO, and other styles

Reports on the topic "Oil reservoir engineering"

1

Shirley P. Dutton, Eugene M. Kim, Ronald F. Broadhead, Caroline L. Breton, William D. Raatz, Stephen C. Ruppel, and Charles Kerans. Play Analysis and Digital Portfolio of Major Oil Reservoirs in the Permian Basin: Application and Transfer of Advanced Geological and Engineering Technologies for Incremental Production Opportunities. Office of Scientific and Technical Information (OSTI), January 2004. http://dx.doi.org/10.2172/909697.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Shirley P. Dutton, Eugene M. Kim, Ronald F. Broadhead, William Raatz, Cari Breton, Stephen C. Ruppel, Charles Kerans, and Mark H. Holtz. PLAY ANALYSIS AND DIGITAL PORTFOLIO OF MAJOR OIL RESERVOIRS IN THE PERMIAN BASIN: APPLICATION AND TRANSFER OF ADVANCED GEOLOGICAL AND ENGINEERING TECHNOLOGIES FOR INCREMENTAL PRODUCTION OPPORTUNITIES. Office of Scientific and Technical Information (OSTI), April 2003. http://dx.doi.org/10.2172/825581.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Shirley P. Dutton, Eugene M. Kim, Ronald F. Broadhead, Caroline L. Breton, William D. Raatz, Stephen C. Ruppel, and Charles Kerans. PLAY ANALYSIS AND DIGITAL PORTFOLIO OF MAJOR OIL RESERVOIRS IN THE PERMIAN BASIN: APPLICATION AND TRANSFER OF ADVANCED GEOLOGICAL AND ENGINEERING TECHNOLOGIES FOR INCREMENTAL PRODUCTION OPPORTUNITIES. Office of Scientific and Technical Information (OSTI), May 2004. http://dx.doi.org/10.2172/828411.

Full text

APA, Harvard, Vancouver, ISO, and other styles

We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!