Dissertations / Theses: '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.

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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.

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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.

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

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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.

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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.

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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.

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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.

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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.

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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.

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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).

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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.

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11

Seth, Siddhartha. "Increase in surface energy by drainage of sandstone and carbonate." Laramie, Wyo. : University of Wyoming, 2006. http://proquest.umi.com/pqdweb?did=1221730011&sid=4&Fmt=2&clientId=18949&RQT=309&VName=PQD.

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12

Artun, F. Emre. "Reservoir characterization using intelligent seismic inversion." Morgantown, W. Va. : [West Virginia University Libraries], 2005. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4185.

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Thesis (M.S.)--West Virginia University, 2005.
Title from document title page. Document formatted into pages; contains xii, 82 p. : ill. (some col.), maps (some col.). Includes abstract. Includes bibliographical references (p. 80-82).

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Luca, Gheorghe. "Toward high definition reservoir characterization." Morgantown, W. Va. : [West Virginia University Libraries], 2001. http://etd.wvu.edu/templates/showETD.cfm?recnum=2175.

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Thesis (M.S.)--West Virginia University, 2001.
Title from document title page. Document formatted into pages; contains xi, 149 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 118-124).

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Van, Ruth Peter John. "Overpressure in the Cooper and Carnarvon Basins, Australia /." Title page, abstract and table of contents only, 2003. http://web4.library.adelaide.edu.au/theses/09PH/09phv275.pdf.

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15

Hægland, Håkon. "Streamline tracing on irregular grids." Bergen : [H. Hægland] ; [Universitetet i Bergen], 2003. http://www.uib.no/people/fcihh/thesis/thesis.pdf.

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Thesis (M.S.)--Universitetet i Bergen, 2003
Hovedoppgave i matematikk - Universitetet i Bergen, 2003 II Title from document title page. Includes bibliographical references. Available in PDF format via the World Wide Web.

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16

Selle, Olav. "An Experimental Study of Viscous Surfactant Flooding for Enhanced Oil Recovery." Thesis, Norwegian University of Science and Technology, Department of Petroleum Engineering and Applied Geophysics, 2006. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-757.

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This Master Thesis work aims to find a model system combining the positive effects of surfactant and polymer flooding to enhance oil recovery. This report presents the results of 12 core floors performed to enhance recovery of waterflood residual oil. The recovery is enhanced by a visous surfactant flood consistent of one polymer to increase the viscosity, one surfactant for interfacial tension reduction, and one di-alcohol to function as co-surfactant and for salinity control.

The chemical treatment that gave the best result, gave an additional oil production normalized on OOIP of 20%, improving the oil recovery from 45 to 66% mostly by the means of mobility control. Pure viscosity floods gave an additional recovery of 12 to 13% of OOIP.

Novel technology is used to investigate environmental friendly enhanced oil recovery. A biopolymer made out of microfibrils from wooden material was for the first time ever to my knowledge, attempted used in a core flood to enhance oil recovery.

A viscous surfactant tertiary recovery process may help improve oil recoveries from many marginal oil fields or those that face shut-down due to uneconomic operating costs, but still contain significant amounts of oil.

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17

Lei, Guowen. "Producing Gas-Oil Ratio Performance of Conventional and Unconventional Reservoirs." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19514.

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This study presents a detailed analysis of producing gas-oil ratio performance characteristics from conventional reservoir to unconventional reservoir. Numerical simulations of various reservoir fluid systems are included for comparison. In a wide sense of the word, the term of unconventional reservoir is including tight gas sand, coal bed methane, gas hydrate deposits, heavy oil gas shale and etc. In this study we specify the unconventional reservoir to only mean the low and ultra low permeability reservoir, which is including tight or shale reservoir. As an emerging research topic in the E&P industry, shale reservoir’s long-term well performance characteristics are generally not well understood (Anderson et al. 2010). Research methods and techniques for conventional reservoir are usually directly used in this unconventional reservoir analysis. These methods, however, have proven to be too pessimistic (Anderson et al., 2010). Fit-for-purpose approaches or solutions should be introduced in this new topic. Recently, hydraulic fracturing treatment is commonly used in the low matrix permeability reservoir to attain an economic production rate. The difference of well production performance between conventional reservoir and unconventional reservoir is not well known. In this study, we are trying to give a quantitative analysis in order to answer this question.In this study, a “generic” reservoir from field data with constant reserves and size were assumed. This reservoir model is homogeneous and of constant porosity, permeability and initial water saturation. In order to compare the production performance, fluid systems are varied from volatile oil to near critical oil, to gas condensate and to wet gas. The permeability of the reservoir model is also designed from high (conventional reservoir) to ultra low (unconventional), which ranges from 101 to 10-5 mD. Influence from fracture is especially considered because fractures in the low permeability reservoir provide a high conductivity that connects the reservoir matrix to the horizontal well. Fractures in the model are designed with identical geometrical characteristics (length, thickness) and of inner homogeneous properties (porosity, permeability).A black-oil model is used for each reservoir, and its PVT properties are generated with a 31 components EOS model using Whitson-Torp procedure (Whitson et al., 1983). Reservoir fluid systems equilibrium calculation in the black-oil model is done using the initial gas-oil ratio. We have compared the well’s production performance for each fluid system.Based on the industry experience, two standards are used in reservoir simulation control: gas production rate and cumulative revenue. The gas production rate with 10 ×106 ft3/day in the first 10 days or the cumulative revenue equal to 5 ×105 USD from the first 10 days is set as the standard for the commercial well rate. All of these simulations are run under the control of these two types which have just been mentioned. A case of liquid rich gas reservoir is analyzed systematically, to compare its production performance when reservoir permeability is changed from high to low. We are interested in how much oil or gas condensate can be extracted from the “reservoir” if same initial fluids in the reservoir but of a different permeability. This study is useful and practical, particularly for the industry in the era of “high” oil price and “low” gas price in North America.The simulation results show that we can extract more liquid from the reservoir if the matrix permeability is higher, particularly for the reservoir with initially large oil contents (volatile oil reservoir, near critical reservoir and gas condensate reservoir). Fracturing treatment in unconventional reservoir is required to attain an economic production rate. We also realize that for the required number of fractures and reservoir’s matrix permeability, there exists linear correlation in log-log plot in the low-permeability reservoir. In this study, the unique optimization software Pipe-It and reservoir simulator SENSOR are used. Optimal simulation results of permeability combination are obtained by the module Optimizer in Pipe-It.

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18

Li, Bowei. "Implementation of full permeability tensor representation in a dual porosity reservoir simulator." Access restricted to users with UT Austin EID Full text (PDF) from UMI/Dissertation Abstracts International, 2001. http://wwwlib.umi.com/cr/utexas/fullcit?p3034930.

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19

Lee, Hyundo. "Development of photo-patterned composite structures in microchannels for oil reservoir research." Thesis, Massachusetts Institute of Technology, 2014. http://hdl.handle.net/1721.1/92220.

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Thesis: S.M., Massachusetts Institute of Technology, Department of Mechanical Engineering, 2014.
Cataloged from PDF version of thesis.
Includes bibliographical references (pages 49-50).
Starting from unstructured glass microchannels, we develop a new method of micromodel fabrication. We build composite structures in a bottom-up manner with ultraviolet projection lithography where the composite structures are composed of tricyclodecane dimethanol diacrylate and stearic-acid treated calcium carbonate particles. This lithographic method is simple, fast, economical, and versatile compared with previous fabrication methods used for two-phase porous media micromodel experiments. With the micromodels developed in this way, we conduct oil-water two-phase flow experiments around a single cylindrical post with controlled oleophilic/hydrophilic wetting behavior.
by Hyundo Lee.
S.M.

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20

Kristamsetty, Venkata. "Application of a statistical zonation technique to Granny Creek field in West Virginia." Morgantown, W. Va. : [West Virginia University Libraries], 2006. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4903.

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Thesis (M.S.)--West Virginia University, 2006.
Title from document title page. Document formatted into pages; contains xx, 159 p. : ill. (some col.), map. Includes abstract. Includes bibliographical references (p. 64-65).

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21

Fischer, Herbert. "Oil recovery by spontaneous imbibition for a wide range of viscosity ratios." Laramie, Wyo. : University of Wyoming, 2006. http://proquest.umi.com/pqdweb?did=1225153481&sid=1&Fmt=2&clientId=18949&RQT=309&VName=PQD.

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22

Sant'Anna, Pizarro Jorge Oscar de. "Estimating injectivity and lateral autocorrelation in heterogeneous media /." Digital version accessible at:, 1998. http://wwwlib.umi.com/cr/utexas/main.

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23

Aldejain, Abdulaziz A. "Implementation of a dual porosity model in a chemical flooding simulator /." Digital version accessible at:, 1999. http://wwwlib.umi.com/cr/utexas/main.

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24

Lin, Paul Hong-Yi. "Data quality enhancement in oil reservoir operations : an application of IPMAP." Thesis, Massachusetts Institute of Technology, 2012. http://hdl.handle.net/1721.1/76569.

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Thesis (S.M. in Engineering and Management)--Massachusetts Institute of Technology, Engineering Systems Division, System Design and Management Program, 2012.
Cataloged from PDF version of thesis.
Includes bibliographical references (p. 70-71).
This thesis presents a study of data quality enhancement opportunities in upstream oil and gas industry. Information Product MAP (IPMAP) methodology is used in reservoir pressure and reservoir simulation data, to propose data quality recommendations for the company under study. In particular, a new 4-step methodology for examining data quality for reservoir pressure management systems is proposed: 1. Trace the data flow and draw the IPMAP; 2. Highlight the cross-system and organizational boundaries; 3. Select data quality analytical questions based on data quality literature review; 4. Apply the analytical questions at each boundary and document the results. This original methodology is applied to the three management systems to collect a pressure survey: using a spreadsheet, a standardized database and an automated database. IPMAPs are drawn to each of these three systems and cross-system and organizational boundaries are highlighted. Next, data quality systematic questions are applied. As a result, three data quality problems are identified and documented: well identifier number, well bore data and reservoir datum. The second experiment investigates the data quality issues in the scope of reservoir simulation and forecasting. A high-level IPMAP and a process flow on reservoir simulation and forecasting are generated. The next section further elaborates on the first high level process flow and drills into the process flow for simulation. The analytical data quality questions are raised to the second simulation process flow and limited findings were documented. This thesis concludes with lessons learned and directions for future research.
by Paul Hong-Yi Lin.
S.M.in Engineering and Management

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25

Gholami, Vida. "Fuzzy rock typing enhancing reservoir simulation and modeling by honoring high resolution geological models /." Morgantown, W. Va. : [West Virginia University Libraries], 2009. http://hdl.handle.net/10450/10555.

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Thesis (M.S.)--West Virginia University, 2009.
Title from document title page. Document formatted into pages; contains xiii, 120 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 89-93).

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26

Dai, Jianchun. "Integrated reservoir characterization of Sun oil and gas field, South Texas /." Digital version accessible at:, 2000. http://wwwlib.umi.com/cr/utexas/main.

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27

Bakhsh, S. "A model study of clay mobilisation and permeability reduction during oil reservoir flooding." Thesis, Loughborough University, 1991. https://dspace.lboro.ac.uk/2134/7119.

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Formation damage effects have been reported in a number of oil reservoirs in secondary and enhanced recovery stages of production. The loss in permeability has been widely attributed to the swelling or pore-plugging action of colloidal clay minerals which are present in varying quantities in the pore spaces of reservoir rocks. This research has been aimed at predicting the action of non-swelling clay particles such as those commonly found in North Sea reservoir sandstones. The literature from the areas of formation damage, colloidal suspensions, and deep bed filtration has been examined with particular attention being given to the subject of clay mineralogy. An experimental test rig was designed, comprising a cylindrical packed sand bed used as a model reservoir to study the permeability changes associated with the action of clay fines under various flooding regimes. The pH, salinity and valency of ionic species present in the flooding fluids were found to be the controlling factors for clay mobilisation. Fines dispersal coincided with spontaneous decrease. in permeability when sandpacks treated with monovalent brine were subjected to fresh water flow. Analysis showed that'the fines released from the bed were primarily kaolinite in the size range 1-5 micron. A minimum critical+ salinity of flooding water was shown to exist, above which particle dispersal is prevented. Further, experimental work provided a measure of the ion exchange capacity of the clay fines in the sandpack as well as of pure clay materials. The close-range interaction of kaolinite particles with silica surfaces was measured in a continuous flow glass apparatus which allowed in-situ observation and measurement by optical microscopy. Particle deposition in this system was found to be very sensitive to the method of cleaning of the silica surface. Deposition was also a function of the suspension flowrate. Clay mobilisation behaviour, as observed in the sandpack experiments, was confirmed with suspension pH, salinity and flowrate to a lesser extent, governing the particle release process. The research has identified the conditions under which clay mobilisation is initiated. It is proposed that any model of permeability reduction should be adapted to include the effects of specific ion-exchange processes between clays and flooding liquids.

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Hird, Kirk B. "A conditional simulation method for reservoir description using geological and well performance constraints /." Access abstract and link to full text, 1993. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9330024.

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29

Awolola, Kazeem Adetayo. "ENHANCED OIL RECOVERY FOR NORNE FIELD (STATOIL) C-SEGMENT USING ALKALINE-SURFACTANT-POLYMER FLOODING." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19259.

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A great percentage of oil is observed to be left in the reservoir after the traditional primary and secondary recovery methods. This oil is described as immobile oil. Alkaline-Surfactants are chemicals used to reduce the interfacial tension between the involved fluids, while polymer is used in making the immobile oil mobile.Norne C-segment is in the decline stage and is facing considerable challenges regardingvolume of oil bye-passed due to water flooding. There is need for developing cost efficient enhanced oil recovery (EOR) methods that would be suitable for Norne fluid and rock properties and therefore improve sweep efficiency significantly. Based on literature and screening criteria, alkaline-surfactant-polymer can be used as an enhancing agent to produce extra oil and reduce water-cut significantly in the C-segment.The objective of this work is to evaluate the possibilities of using alkaline, surfactant and/or polymer to increase the oil recovery factor and prolong the production decline stage of Norne field. An initial study was conducted using heterogeneous synthetic models (with Norne Csegment fluids and rock properties) to assess the suitability of alkaline/surfactant/polymer (ASP) flooding. All the chemical cases simulated gave substantial incremental oil production and water-cut reduction. However, history matched Norne C-segment reservoir model was used to simulate alkalinesurfactant-polymer flooding using Eclipse 100. Appropriate chemical quantity for injection was ascertained by simulating several cases with different concentration, injection length and time of injection. Different sensitivity analyses were made and simulations revealed that the most effective method was not the most profitable. Having established most profitable method which was injecting ASP slug with a concentration of 7Kg/m3, 2Kg/m3 and 0.3Kg/m3 into C-3H (injector) for 4-years in a cyclic manner, an incremental recovery factor of 2.61% was recorded and Net Present Value (NPV) was calculated to be 1660 x103MNOK

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30

Mendez, Zuleyka del Carmen. "Flow of dilute oil-in-water emulsions in porous media /." Digital version accessible at:, 1999. http://wwwlib.umi.com/cr/utexas/main.

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31

Tong, Zhengxin. "Oil recovery by spontaneous imbibition from mixed-wet rocks." Laramie, Wyo. : University of Wyoming, 2005. http://proquest.umi.com/pqdweb?did=888851021&sid=2&Fmt=2&clientId=18949&RQT=309&VName=PQD.

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32

Atthawutthisin, Natthaporn. "Numerical Simulation of Low Salinity Water Flooding Assisted with Chemical Flooding for Enhanced Oil Recovery." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19113.

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World proved oil reserve gradually decreases due to the increase production but decrease new field discovery. The focus on enhance oil recovery from the existing fields has become more interesting in the recent years. Since waterflooding has been used in practices in secondary recovery phase for long time ago, the low salinity waterflooding is possible to apply as tertiary recovery phase. Another effective enhance oil recovery method is chemical flooding especially, nowadays, when the price of chemical is not a big issue compared to oil price. Both low salinity and chemical flooding method have been trialed and success in laboratory studies and some field tests. Moreover the salinity sensitivity on chemical flooding has been studied and both positive and negative results were proposed. Because new technology has been developing day by day in order to get higher oil recovery, the new technology as the combination of low salinity waterflooding and chemical flooding has been studied in this report. In this thesis, the literature of low salinity water flooding, alkaline flooding, surfactant flooding, polymer flooding and alkaline-surfactant-polymer flooding (ASP) have been reviewed. The mechanisms of each method that affect to oil recovery and salinity sensitivity on each chemical flooding method have been summarized. All of those studies showed the benefit of chemical to the low salinity water flooding. the result of literature reviews has turned to the numerical simulation part.The simulation has been carried out on a 3 dimensional synthetic model by using Eclipse 100 as the simulator. The model is heterogeneous with patterns variation in permeability and porosity. The effect of low salinity in water flooding, alkaline flooding, surfactant flooding, polymer flooding and ASP flooding have been observed in many aspects.The main role of low salinity effect in water flooding is wettability changing from oil-wet to water-wet. The low salinity water in the first water flooding phase give the positive effect but not much different compared to overall recovery. The low salinity in chemical solution influences an additional oil recovery in all combinations. Mainly, low salinity increases polymer solution viscosity that can improve sweep efficiency of polymer flooding. In alkaline flooding and surfactant flooding, the salinity is need to be optimized to optimum salinity condition corresponding to optimum alkaline concentration and surfactant concentration, where creates the lowest IFT. The range of secondary flooding for alkaline and surfactant flooding is when they reach the optimum concentration. In case of polymer, the viscous polymer solution can impact longer as the polymer injection range. In term of low salinity in tertiary water flooding, it influences better oil recovery than high salinity water flooding. Therefore, it can be concluded that low salinity water flooding gives a positive effect to overall result when combined with chemical flooding. The recommendations are also available for further study.

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Akpan, Stella Eyo. ""Well Placement for maximum production in the Norwegian Sea" : Case Study: Norne C-segment Oil Field." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19960.

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In petroleum fields, the essence of well placement is to develop and maintain petroleum reservoirs in order to achieve maximum production for economic benefit. Maximum production can be achieved with more oil wells, but few optimal numbers of wells in good location reduces economic costs and increase recovery. The best location for the placement of oil, gas or water wells depends on reservoir and fluid properties, well and surface equipment specifications, as well as economic parameters [1].The objective of the study is to determine the net present value from few well placements in the Norne C-segment reservoir by either obtaining the same or more oil production/recovery compared to the base case wells. New well placement in a reservoir simulation model uses an industrial standard ECLIPSE reservoir simulator. Manually simulation approach is used to locate high oil saturation grids for the new well placement. From the base case simulation result, a total number of thirteen wells were discovered, nine producers and four injectors. The production and injection wells were classified with a suffix according to the production templates B, D, K and injection template C respectively.The base case wells removed and new well placed from exhaustive simulation runs for two different scenario cases. A total number of ten wells, six producers and four injectors were placed in each scenario. In order to obtain maximum oil recovery, the producers are placed horizontally while injectors remain the same as those from the base case. The new well placements in the scenario cases are identified with the suffix “P-H” for producers and “I-H” for injectors. Simulation results, the total oil produced for wells in each field case from the start year 1997 to December 2015, (end of production) can be seen in Table 10, 11 and 12 in chapter 6. The cumulative oil produced from each field case is the same as the total oil produced from all the wells in each case. The cumulative field oil and gas production from the start of production, November 1997 to December 2015 is 41.3 million Sm3 oil and 260 million Sm3 of gas for base case, 42.8 million Sm3 oil and 269 million Sm3 of gas for scenario 1 case, 43.2 million Sm3 oil and 272 million Sm3 of gas for scenario 2 case. The recovery factor for base case is 28%, scenario 1 & 2 are 29.0% and 29.3%. Each field case uses drive mechanisms, gas injection and water injection to support oil production and maintain pressure in the each field case. The total gas and water injected in the base case field were 9.6 billion Sm3 and 78.8 million Sm3 respectively. In scenario 1, a total of 8.6 billion Sm3 of gas and 81.6 million Sm3 of water was injected and in Scenario 2, 8.6 billion Sm3 of gas and 81.3 million Sm3 of water was injected. The Net present values for the three cases were calculated taking into account the economic costs such as well cost, cost of gas and water injection. Sensitization was done on the oil price ($25, $35 and $45). The NPV results from Table 19 prove that all case projects are acceptable, but scenario 2 is the most economical as it has the highest NPV of $4,026 million based on $35-medium oil price that was considered.

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Mata, Domingo A. "Validation of a new technique of production data analysis for single and multi-layer formations under controlled environment." Morgantown, W. Va. : [West Virginia University Libraries], 2007. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=5369.

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Thesis (M.S.)--West Virginia University, 2007.
Title from document title page. Document formatted into pages; contains viii, 105 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 95).

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Pereira, Janaina Luiza Lobato. "Permeability prediction from well log data using multiple regression analysis." Morgantown, W. Va. : [West Virginia University Libraries], 2004. https://etd.wvu.edu/etd/controller.jsp?moduleName=documentdata&jsp%5FetdId=3368.

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Thesis (M.S.)--West Virginia University, 2004.
Title from document title page. Document formatted into pages; contains xiii, 82 p. : ill. (some col.), maps. Vita. Includes abstract. Includes bibliographical references (p. 41).

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Gonzalez, Daniel G. "Basic building blocks of real-time data analysis as applied to smart oil fields." Morgantown, W. Va. : [West Virginia University Libraries], 2007. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=5370.

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Thesis (M.S.)--West Virginia University, 2007.
Title from document title page. Document formatted into pages; contains xii, 136 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 75-76).

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37

Abadli, Farid. "Simulation Study of Enhanced Oil Recovery by ASP (Alkaline, Surfactant and Polymer) Flooding for Norne Field C-segment." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19432.

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This research is a simulation study to improve total oil production using ASP flooding method based on simulation model of Norne field C-segment. The black oil model was used for simulations. Remaining oil in the reservoir can be divided into two classes, firstly residual oil to the water flood and secondly oil bypassed by the water flood. Residual oil mainly contains capillary trapped oil. Water flooding only is not able to produce capillary trapped oil so that there is a need for additional technique and force to produce as much as residual oil. One way of recovering this capillary trapped oil is by adding chemicals such as surfactant and alkaline to the injected water. Surfactants are considered for enhanced oil recovery by reduction of oil–water interfacial tension (IFT). The crucial role of alkali in an alkaline surfactant process is to reduce adsorption of surfactant during displacement through the formation. Also alkali is beneficial for reduction of oil-water IFT by in situ generation of soap, which is an anionic surfactant. Generally alkali is injected with surfactant together. On the other hand, polymer is very effective addition by increasing water viscosity which controls water mobility thus improving the sweep efficiency.In the first place, ASP flooding was simulated and studied for one dimensional, two dimensional and three dimensional synthetic models. All these models were built based on C-segment rock properties and reservoir parameters. Based on test runs, well C-3H was selected and used as a main injector in order to execute chemical injection schemes in the C-segment. Five studies such as polymer flooding, surfactant flooding, surfactant-polymer flooding, alkaline-surfactant and alkaline-surfactant-polymer flooding were considered in the injection process and important results from simulator were analyzed and interpreted. Sensitivity analyses were done especially focusing on chemical solution concentration, injection rate and duration of injection time. The polymer flooding project in this study has shown a better outcome compared to water flooding project. Economically best ASP solution flooding case is the flooding with concentration of alkaline at1.5kg/m3, surfactant at 15kg/m3 and polymer at 0.35 kg/m3 injecting for 5 years. AS flooding case for 4 years with alkali concentration at 0.5kg/m3 and surfactant concentration at 25 kg/m3 gave highest NPV value. It was found that surfactant flooding has a promising effect and it is more profitable than polymer flooding for the C segment in terms of NPV. Economic sensitivity analysis (Spider diagram) for low case, base case and high case at different oil prices, chemicals prices, and discount rate were also presented. It was found that change in oil price has significant effect on NPV compared to other parameters while polymer price has the least effect on NPV for high and low cases.

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38

Zhao, Yong. "Ensemble Kalman filter method for Gaussian and non-Gaussian priors /." Access abstract and link to full text, 2008. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/3305718.

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39

Elias, Samya Daniela de Sousa. "Synthesis of a high performance surfactant for application in alkaline-surfactant-polymer flooding in extreme reservoirs." Thesis, Cape Peninsula University of Technology, 2016. http://hdl.handle.net/20.500.11838/2491.

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Thesis (MTech (Chemical Engineering))--Cape Peninsula University of Technology, 2016.
Due to the rising cost involve with bringing new fields on stream, of producing residual crude from matured fields, and the significant enhancement in oil recovery provided when compared to conventional water-flooding, increasing attention is being given to chemical flooding technologies. This is particular of interest in mature fields that had previously undergone water flooding. These methods entail injecting chemicals such as surfactant, alkali, and polymer often in mixture into reservoirs to improve oil recovery. In this study a sulfonated surfactant was produced from cheap waste vegetable oils and its performance was assessed in terms of thermal stability at reservoir conditions, adsorption on different reservoir materials, gas chromatography characterization and a limited interfacial tension measurement to evaluate its ability to improve the recovery of crude oil. Waste vegetable oils have great potential as a sustainable and low cost feedstock as well as its low toxicity.

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Gil, Edison. "Improving the simulation of a waterflooding recovery process using artificial neural networks." Morgantown, W. Va. : [West Virginia University Libraries], 2000. http://etd.wvu.edu/templates/showETD.cfm?recnum=1662.

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Thesis (M.S.)--West Virginia University, 2000.
Title from document title page. Document formatted into pages; contains xi, 94 p. : ill. (some col.), maps. Includes abstract. Includes bibliographical references (p. 63-64).

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41

Rolon, Luisa F. "Developing intelligent synthetic logs application to Upper Devonian units in PA /." Morgantown, W. Va. : [West Virginia University Libraries], 2004. https://etd.wvu.edu/etd/controller.jsp?moduleName=documentdata&jsp%5FetdId=3721.

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Thesis (M.S.)--West Virginia University, 2004.
Title from document title page. Document formatted into pages; contains ix, 123 p. : ill. (some col.), maps (some col.). Includes abstract. Includes bibliographical references (p. 108-109).

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42

Sarkar, Sume. "Evaluation of Alkaline, Surfactant and Polymer Flooding for Enhanced Oil Recovery in the Norne E-segment Based on Applied Reservoir Simulation." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19958.

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The world needs energy – and over the short and medium term it is clear that much of our global energy consumption will come from fossil sources such as oil, gas and coal. With the current growing demand for oil led by major energy consuming countries such as China and India, securing new oil resources is a critical challenge for the oil industry. Each year, new production is needed to compensate the natural decline of existing wells, and the additional production required to satisfy the yearly demand for hydrocarbon energy that will represent approximately 9% of the worldwide total production. For this growth to be sustainable, a strong focus will have to be placed on finding new discoveries and/or optimizing oil production from current resources. The cost associated with the first option is significant. Therefore, reservoir management teams all over the world will have to cater for this demand mainly by maximizing hydrocarbon recovery factors through Enhanced Oil Recovery (EOR) processes. EOR consists of methods aimed at increasing ultimate oil recovery by injecting appropriate agents not normally present in the reservoir, such as chemicals, solvents, oxidizers and heat carriers in order to induce new mechanisms for displacing oil. Chemical flooding is one of the most promising and broadly applied EOR processes which have enjoyed significant research and pilot testing during the 1980s with a significant revival in recent years. However, its commercial implementation has been facing several technical, operational and economic challenges. Chemical flooding is further subdivided into polymer flooding, surfactant flooding, alkaline flooding, miscellar flooding, alkaline-surfactant-polymer (ASP) flooding. ASP flooding is a form of chemical enhanced oil recovery (EOR) that can allow operators to extend reservoir pool life and extract incremental reserves currently inaccessible by conventional EOR techniques such as waterflooding. Three chemical inject in the ASP process which is synergistic. In the ASP process, Surfactants are chemicals that used to reduce the interfacial tension between the involved fluids, making the immobile oil mobile. Alkali reduces adsorption of the surfactant on the rock surfaces and reacts with acids in the oil to create natural surfactant. Polymer improves the sweep efficiency. By simulating ASP flooding for several cases, with different chemical concentrations, injection length, time of injection, current well optimization and new well placement, this report suggests a number of good alternatives. Simulations showed that the most effective method was not the most profitable. From the simulation results and economic analysis, ASP flooding can be a good alternative for the Norne E-segment. But the margins are not significant, so fixed costs (such as equipment rental) will be of crucial importance.

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43

Mohamad, Khalid Y. "Restimulation candidate selection using virtual intelligence." Morgantown, W. Va. : [West Virginia University Libraries], 2000. http://etd.wvu.edu/templates/showETD.cfm?recnum=1722.

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Thesis (M.S.)--West Virginia University, 2000.
Title from document title page. Document formatted into pages; contains ix, 176 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 64-65).

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44

Al-Qahtani, Fahad A. "Porosity distribution prediction using artificial neural networks." Morgantown, W. Va. : [West Virginia University Libraries], 2000. http://etd.wvu.edu/templates/showETD.cfm?recnum=1284.

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Thesis (M.S.)--West Virginia University, 2000.
Title from document title page. Document formatted into pages; contains viii, 63 p. : ill. (some col.), maps Includes abstract. Includes bibliographical references (p. 54-55).

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Riera, Alexis J. "Predicting permeability and flow capacity distribution with back-propagation artificial neural networks." Morgantown, W. Va. : [West Virginia University Libraries], 2000. http://etd.wvu.edu/templates/showETD.cfm?recnum=1309.

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Thesis (M.S.)--West Virginia University, 2000.
Title from document title page. Document formatted into pages; contains xii, 86 p. : ill. (some col.), maps. Includes abstract. Includes bibliographical references (p. 61-63).

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46

Kapur, Loveena. "Investigation of artificial neural networks, alternating conditional expectation, and Bayesian methods for reservoir characterization /." Digital version accessible at:, 1998. http://wwwlib.umi.com/cr/utexas/main.

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Arns, Christoph Hermann Petroleum Engineering Faculty of Engineering UNSW. "The influence of morphology on physical properties of reservoir rocks." Awarded by:University of New South Wales. Petroleum Engineering, 2002. http://handle.unsw.edu.au/1959.4/18257.

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We consider the structural and physical properties of complex model morphologies and microstructures obtained by Xray-CT imaging. The Minkowski functionals, a family of statistical measures based on the Euler-Poincaré characteristic of n-dimensional space, are shown to be sensitive measures of the morphology of disordered structures. Analytic results for the Boolean model are given and used to devise a reconstruction scheme, which allows one to accurately reconstruct a complex Boolean structure given at any phase fraction for all other phase fractions. The percolation thresholds of either phase are obtained with good accuracy. From the reconstructions one can subsequently predict property curves for the material across all phase fractions from a single 3D image. We illustrate this for transport and mechanical properties of complex Boolean systems and for experimental sandstone samples. By extending the Minkowski functionals to parallel surfaces using operations from mathematical morphology, a powerful discrimination of structure is obtained. Further the sensitivity of the Minkowski functionals under experimental conditions is analysed. Accurate calculations of conductive and elastic properties directly from tomographic images are achieved by estimating and minimising several sources of numerical error. Simulations of electrical conductivity and linear elastic properties on microtomographic images of Fontainebleau sandstone are in excellent agreement with experimental measurements over a wide range of porosity. The results show the feasibility of combining digitised images with transport and elasticity calculations to accurately predict physical properties of individual material morphologies. We show that measurements of properties based on microtomographic images are more accurate than those based on conventional theories for disordered materials. We study the elastic behaviour of model clean and cemented sandstones. Results are in excellent agreement with available experimental data, and are compared to conventional theoretical and empirical laws. A new predictive empirical method is given for predicting the elastic moduli of sandstone morphologies. The method gives an excellent match to numerical and experimental data.

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Ribeiro, Junior Guilherme Blaitterman. "Simulação numerica de combustão "In-situ" em escala laboratorial." [s.n.], 2009. http://repositorio.unicamp.br/jspui/handle/REPOSIP/264269.

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Orientador: Osvair Vidal Trevisan
Dissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociencias
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Resumo: Como as reservas mundiais de óleo leve estão decrescendo continuamente, campos de óleos pesados podem se tornar uma fonte relevante de energia em um futuro próximo. Combustão "In- Situ" (CIS) é uma promissora técnica de recuperação para este tipo de hidrocarboneto, todavia, complexa de se implementar. Tubos de combustão em escala laboratorial e simulações numéricas são essenciais para o dimensionamento de projetos de campo. Este trabalho relata a modelagem numérica de dois experimentos efetuados em escala de laboratório de processos de CIS com um óleo com 12,8º API advindo de um campo candidato para um projeto piloto no Brasil. O estudo numérico foi desenvolvido utilizando o software comercial da CMG, STARS. O objetivo foi analisar o processo, para um modelo físico correspondente ao tubo de combustão utilizado. O modelo de fluido foi ajustado através de um software comercial para um total de sete componentes, óleo pesado, óleo leve, CO2, O2, N2, H2O e coque. Dois processos de combustão foram investigados, o primeiro é o modelo clássico descrito pelo STARS da CMG e o segundo é baseado no modelo de Marín (2007), constituído de frações SARA (saturados, aromáticos, resinas e asfalteno). Os resultados numéricos foram ajustados de acordo com os dados obtidos do experimento. As conclusões sobre este estudo se referem às influências de cada variável sobre o processo global de CIS, em especial a energia de ativação e a entalpia de reação. Além disso, conclui-se que o modelo de fluido e o modelo de reações são fundamentais no ajuste de histórico, assim como a presença de reações sob altas temperaturas são imprescindíveis para se predizer o deslocamento e comportamento da frente de combustão.
Abstract: As the world reserves of light oil steadily decreases, heavy oil and tar sands resources may be an important source of energy. In situ combustion (ISC) is a promising recovery technique for this type of hydrocarbon, otherwise difficult to produce. Combustion tube laboratory experiments and numerical simulations are essential for the design of field projects. This work reports a numeric modeling of two experiments carried out under laboratory scale of in situ combustion process with a 12.8 ºAPI crude from a field candidate to a pilot project in Brazil. The numerical study was developed using the CMG commercial simulator, STARS. The aim was to analyze the process of the physical model corresponding to the combustion tube used. The fluid model was adjusted by a commercial software to a total of 7 components; heavy oil, light oil, CO2, O2, N2, H2O and coke. Two reactions model were analyzed; one is based on the classic combustion model presented by STARS and the other is based on the reactions model proposed by Marín (2007), made up of SARA (saturates, aromatics, resins, and asphaltenes) fractions. The numerical results were history matched to the data derived from the experiment. The important findings in this study were the influences of each variable on the overall ISC process, specifically the activation energy and the enthalpy reaction. It was concluded that the fluid model and the reaction model are key in the history matching task, as well as, the reactions under high temperatures are fundamental to model the combustion front displacement and behavior.
Mestrado
Reservatórios e Gestão
Mestre em Ciências e Engenharia de Petróleo

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Hardy, Benjamin Arik. "A New Method for the Rapid Calculation of Finely-Gridded Reservoir Simulation Pressures." Diss., CLICK HERE for online access, 2005. http://contentdm.lib.byu.edu/ETD/image/etd1123.pdf.

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Mercado, Sierra Diana Patricia 1981. "Modelo pseudocinético para a simulação numérica da combustão in-situ na escala da campo." [s.n.], 2015. http://repositorio.unicamp.br/jspui/handle/REPOSIP/265773.

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Orientador: Osvair Vidal Trevisa
Tese (doutorado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências
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Resumo: A combustão in-situ é um processo multiescala, multifísico que envolve simultaneamente o escoamento de fluidos no meio poroso, o equilíbrio de fases e a cinética das reações químicas. A simulação desse processo tem alcançado um elevado grau de desenvolvimento, no entanto, mecanismos básicos ainda são representados de maneira incompleta, impondo inúmeros desafios na modelagem. A dificuldade de modelar fenômenos relacionados com a combustão tem a ver com a representação do efeito da frente de combustão e a modelagem do consumo de combustível. Na combustão in-situ as reações químicas acontecem em uma zona delgada de menos de um metro de espessura, que é pequena quando comparada com a escala do reservatório de centenas ou milhares de metros. Na simulação na escala de campo, o uso de células de tamanho maior do que a zona de reação leva a erros na distribuição da temperatura. Consequentemente, a velocidade das reações não pode ser bem representada. De outro lado, os simuladores não permitem controlar a ocorrência das reações a partir da energia de ativação. Como resultado, o início das reações se torna independente da temperatura. O objetivo desta tese é desenvolver um modelo pseudocinético para a simulação numérica da combustão in-situ na escala de campo. Com o modelo pseudocinético pretende-se representar os fenômenos na zona de combustão, reduzindo o efeito do tamanho de célula. O trabalho foi desenvolvido em etapas. Primeiro foram estabelecidas as condições que o simulador deveria atender e definida a estratégia de abordagem, que foi a de desenvolver um modelo pseudocinético. Depois foi definida a metodologia de obtenção do modelo pseudocinético. Após o modelo pseudocinético concluído, este foi utilizado para a simulação de um campo de óleo pesado brasileiro submetido à combustão in-situ. O modelo pseudocinético proposto consiste em expressar a energia de ativação das reações em função da temperatura. Através do modelo, é possível restringir a ocorrência da reação de craqueamento, de modo que o início da formação do coque aconteça somente para temperaturas acima dos valores observados na zona de craqueamento. Note-se que neste cenário a quantidade de coque depositado pode ser modelada usando a reação de craqueamento, o que se constitui numa das principais contribuições do trabalho. O modelo permite manter a dependência da taxa de reação com a temperatura mediante o uso de valores de energia de ativação apropriados. Além disso, consegue-se reduzir o efeito da distribuição de temperatura mediante o controle da taxa de reação em função dos valores médios de temperatura observados nas células do modelo de simulação na escala de campo. Na simulação do piloto de combustão in-situ, o modelo pseudocinético foi obtido do ajuste progressivo dos parâmetros cinéticos das reações químicas, partindo da simulação do processo na escala de laboratório até a escala de campo. Os dados experimentais utilizados na simulação na escala de laboratório foram obtidos de um ensaio em tubo de combustão seca realizado no Laboratório de Métodos Térmicos de Recuperação do Departamento de Energia da UNICAMP. O fluido utilizado foi um óleo pesado de 15,3 °API proveniente da Bacia do Espírito Santo
Abstract: The in-situ combustion is a multi-scale, multi-physics process, involving fluid flow in porous media, thermodynamic equilibrium of the phases involved and chemical kinetics of reactions. The simulation of this process has achieved a high degree of development, however basic mechanisms are still represented incompletely, imposing numerous challenges in modeling. The issues in the combustion modeling are related with the representation of the combustion front effect and the fuel consumption modeling. Chemical reactions of the in-situ combustion process take place in a thin zone of less than a meter thick, which is small compared to the field scale of hundreds or thousands of meters. Numerical simulations at the field scale typically use grid blocks that are at least two orders of magnitude greater than that. Such divergence leads to improper representations of key aspects of the process, as the temperature distribution and the reaction kinetics. In accordance with that the reaction occurrence is not controlled by the activation energy in the simulation models. The major shortcome is on fuel deposition, a key issue in in-situ combustion, which will happen from the start, since the cracking reaction may proceed even at reservoir temperature. The objective of this thesis is to develop a new pseudokinetic model for field-scale simulation of in-situ combustion. With the pseudokinetic model meant to improve the representation of the combustion zone effects reducing the gridblock size effect. The work was carried out in stages. First establishes the conditions that the simulator should meet and defined the strategy to develop a pseudokinetic model. Then a methodology was defined for obtaining the pseudokinetic model. After the pseudokinetic model is completed, it is applied to the in-situ combustion modeling of a Brazilian heavy oil field. The models pursue the idea of making the activation energy a function of the grid block temperature. The model allows restricting the cracking reaction occurrence by the temperature, so that the beginning of the coke deposition occurs at temperatures greater than the temperature observed in the cracking zone. Note that in this scenario the cracking reaction can be used to represent the coke deposition, which constitutes one of the main contributions of this work. The model allows maintaining the dependence of reaction rate with temperature through the use of appropriate activation energy values. Furthermore, the model reduces the temperature distribution effect by controlling the reaction rate based on average temperature values observed in the field simulation model. In the simulation of the in-situ combustion pilot, the pseudokinetic model was obtained from the progressive tuning of the kinetic parameters of chemical reactions, based on the simulation of the process from the laboratory to field scale. The experimental data used in the laboratory scale simulation were obtained from a dry combustion tube test carried out at the Thermal Recovery Methods Laboratory of the Energy Department at UNICAMP. The fluid used was a 15.3 ° API heavy oil from the Espírito Santo Basin
Doutorado
Reservatórios e Gestão
Doutora em Ciências e Engenharia de Petróleo

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Dissertations / Theses on the topic 'Oil reservoir engineering'

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