subject:(Petroleum Engineering)

Texas A&M University

1. Prachumchon, Sompong. Semi-analytical methods for the analysis and interpretation of well test data distorted by wellbore storage and skin effects.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-P72

► Our objective is to develop approximations of the pressure-time behavior for use in analyzing the pressure response of a well in an infinite-acting reservoir influenced… (more)

▼ Our objective is to develop approximations of the pressure-time behavior for use in analyzing the pressure response of a well in an infinite-acting reservoir influenced by wellbore storage and skin effects. Our resulting approximate models are semi-analytical, closed-form solutions. We propose five approximate models by assuming the behavior of dimensionless constant rate pressure at the sandface, P,D(tD), as follows: [ ] The advantage of our approach is that these solutions can be used to predict the pressure behavior of a well influenced by wellbore storage and skin effects in the real time domain. To our knowledge, this work is the first attempt to develop and apply real time domain solutions for all times of interest. To verify our new P,,CD(tD) models, we used the numerical inversion solution as the exact solution for wellbore pressure behavior that has been influenced by wellbore storage and skin effects. In particular, we have focused on the cylindrical source solution. As a comparison, we generated the "type curve" solutions for a well in an infinite-acting reservoir with wellbore storage and skin effects using the numerical inversion solution (as the "exact" solution) and our new relations as the "approximate" solutions. We also provided a graphical comparison of the residuals for each approximate solution (as compared to the numerical solution). All of the approximate solutions exhibited excellent agreement and consistency with the numerical inversion solution (except for Model 2). As a practical consideration, we found that it is generally better to compute the pressure derivative functions numerically, rather than by analytical differentiation, because in most cases the analytical derivatives are too tedious for hand calculations. For practical applications, we compare our new solutions to a number of field data cases. In order to perform history-matching of our new solutions, as well as the numerical inversion solution we developed and applied new modules for the historymatching program (PERANA). Again, for comparison, the results from the numerical inversion solution are used as the base results. In general, all of the models are as accurate as the Laplace transform numerical inversion solution, though Model I is clearly not appropriate in certain cases.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Prachumchon, S. (2012). Semi-analytical methods for the analysis and interpretation of well test data distorted by wellbore storage and skin effects. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-P72

Chicago Manual of Style (16^th Edition):

Prachumchon, Sompong. “Semi-analytical methods for the analysis and interpretation of well test data distorted by wellbore storage and skin effects.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-P72.

MLA Handbook (7^th Edition):

Prachumchon, Sompong. “Semi-analytical methods for the analysis and interpretation of well test data distorted by wellbore storage and skin effects.” 2012. Web. 11 Apr 2021.

Vancouver:

Prachumchon S. Semi-analytical methods for the analysis and interpretation of well test data distorted by wellbore storage and skin effects. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-P72.

Council of Science Editors:

Prachumchon S. Semi-analytical methods for the analysis and interpretation of well test data distorted by wellbore storage and skin effects. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-P72

Texas A&M University

2. Saavedra, Nestor Fernando. Chemical wellbore plug for zone isolation in horizontal wells.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-S22

► A new technique for zone isolation in horizontal wells has been proposed. The new technique consists of three sequential stages: (i) setting a chemical wellbore… (more)

▼ A new technique for zone isolation in horizontal wells has been proposed. The new technique consists of three sequential stages: (i) setting a chemical wellbore plug in the horizontal section upstream of the zone to be isolated, (ii) spotting a gel just downstream of the wellbore plug and squeezing the gel into the zone to be isolated, and (iii) washing or drilling through excess gel and the wellbore plug to clean the borehole prior to production. The main objective of this research is to investigate the feasibility of setting a chemical wellbore plug in a horizontal wellbore. Two main problems associated with the wellbore plug were investigated: (a) method of placement of the plug so that slumping would not occur, and (b) selection and testing of chemicals that could be used to make wellbore plugs with sufficiently high holding pressures. Three chemicals, used in the oil industry for gas and/or water shut-off, were selected for the study. The commercial names of these chemicals were SEAL, PERMASEAL and TEXPLUG. Experimental apparatus were designed and constructed to study placement techniques and to measure the holding pressures of the wellbore plugs. The horizontal wellbore models consisted of PVC pipes internally lined with sand. The X-ray CT scanner was used to obtain cross-sectional images of the plug to help understand the shear mechanisms involved. The experimental results indicate that a plug could be placed in a horizontal wellbore with minimum slumping, if the plug is introduced into a viscous completion brine pill. For TEXPLUG, a suitable completion brine would contain 100,000 ppm NaCi and 4 lb/bbl CMC (carboxyl methyl cellulose). Further, results indicate that only TEXPLUG has a sufficiently high holding pressure (about 340 psi for 37 in. long, 1 in. I.D. plug) necessary for a wellbore plug. Based on experimental results, the proposed new isolation technique appears to be viable. However, further experimental studies are required, particularly to evaluate the effectiveness of the wellbore plug in conjunction with displacement of formation gels.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Saavedra, N. F. (2012). Chemical wellbore plug for zone isolation in horizontal wells. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-S22

Chicago Manual of Style (16^th Edition):

Saavedra, Nestor Fernando. “Chemical wellbore plug for zone isolation in horizontal wells.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-S22.

MLA Handbook (7^th Edition):

Saavedra, Nestor Fernando. “Chemical wellbore plug for zone isolation in horizontal wells.” 2012. Web. 11 Apr 2021.

Vancouver:

Saavedra NF. Chemical wellbore plug for zone isolation in horizontal wells. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-S22.

Council of Science Editors:

Saavedra NF. Chemical wellbore plug for zone isolation in horizontal wells. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-S22

Texas A&M University

3. Tunison, Douglas Irvin. Streamline simulation of Surfactant Enhanced Aquifer Remediation.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-T77

► Nonaqueous Phase Liquids (NAPLS) are a recognized source of groundwater contamination. Surfactant Enhanced Aquifer Remediation (SEAR) shows promise in increasing the efficiency and effectiveness over… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Tunison, D. I. (2012). Streamline simulation of Surfactant Enhanced Aquifer Remediation. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-T77

Chicago Manual of Style (16^th Edition):

Tunison, Douglas Irvin. “Streamline simulation of Surfactant Enhanced Aquifer Remediation.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-T77.

MLA Handbook (7^th Edition):

Tunison, Douglas Irvin. “Streamline simulation of Surfactant Enhanced Aquifer Remediation.” 2012. Web. 11 Apr 2021.

Vancouver:

Tunison DI. Streamline simulation of Surfactant Enhanced Aquifer Remediation. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-T77.

Council of Science Editors:

Tunison DI. Streamline simulation of Surfactant Enhanced Aquifer Remediation. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-T77

Texas A&M University

4. Velarde, Jorge Javier. Correlation of black oil properties at pressures below the bubble-point.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-V45

► In the practice of petroleum reservoir engineering we are often faced with the analysis of processes which require the physical properties of the reservoir fluids,… (more)

▼ In the practice of petroleum reservoir engineering we are often faced with the analysis of processes which require the physical properties of the reservoir fluids, but in many cases no laboratory measurements of properties are available. Our only recourse in such cases is the use of empirically derived correlations This study considers the correlation of black oil Pressure-Volume-Temperature (PVT) properties for pressures at or below the bubble-point pressure. Specifically, we address the following correlations: Bubble-point pressure, Pb *Solution gas-oil-ratio at pressures below the bubble-point, Rs ³Oil formation volume factor at pressures below the bubble-point, B0 In this work we provide a detailed analysis of the most popular correlations in the petroleum literature compared to our two databases (P<Pb, 2213 data points; P= Pb, 728 data points). Our analysis shows that all these correlations have limitations in predicting the behavior of Rs and Bo at pressures below the bubble-point. This is somewhat expected as these correlations were developed specifically to estimate fluid properties at the bubblepoint pressure. Our first effort was to correlate Pb- In this effort we tried several relations, but we ultimately used the "Standing-Petrosky" model. Regressing this equation onto our bubblepoint pressure database we obtained an absolute average error of 1 1.7%. Our approach in developing a new correlation for Rs at pressures below the bubble-point considered the use of the "reduced" variables p, and Rsr' This correlation for Rs (P< Pb) gave an absolute average error on the order of 4%. Similarly, correlating these data using our p, correlation we obtained an absolute average error of 8.4%. A similar reduced variables approach was attempted and abandoned for the correlation of B, (P< Pb), primarily due to our inability to correlate low pressure behavior. We instead used Standing's model; this correlation for B,, (P< Pb) gave an absolute average error on the order of 2%. We also developed a material balance procedure for the determination of Bo using R, from our new correlation and a pseudo-liquid density correlation published by McCain and Hill. This correlation also gave an absolute average error of approximately 2%.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Velarde, J. J. (2012). Correlation of black oil properties at pressures below the bubble-point. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-V45

Chicago Manual of Style (16^th Edition):

Velarde, Jorge Javier. “Correlation of black oil properties at pressures below the bubble-point.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-V45.

MLA Handbook (7^th Edition):

Velarde, Jorge Javier. “Correlation of black oil properties at pressures below the bubble-point.” 2012. Web. 11 Apr 2021.

Vancouver:

Velarde JJ. Correlation of black oil properties at pressures below the bubble-point. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-V45.

Council of Science Editors:

Velarde JJ. Correlation of black oil properties at pressures below the bubble-point. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1996-THESIS-V45

Texas A&M University

5. Cobenas, Rafael H. A closer look at non-uniqueness during dynamic data integration.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C63

► Characterizing heterogeneous permeable media using dynamic data such as transient pressure, tracer or multiphase production history typically requires the solution of an inverse problem. These… (more)

▼ Characterizing heterogeneous permeable media using dynamic data such as transient pressure, tracer or multiphase production history typically requires the solution of an inverse problem. These inverse problems apart from being computationally intensive are ill-posed by essence. The solutions of such inverse problems present two undesirable characteristics, instability and non-uniqueness. In order to overcome these difficulties, the addition of a regularization term is required in the inversion procedure. These regularization techniques can be grouped, depending on the approach selected, as being stochastic or deterministic. Both methods have been described and used with success in related sciences like geophysics and groundwater resources. Our objective is to show analytically and graphically the interrelation between these two techniques as well as their usefulness for obtaining better inverse solutions. In this thesis we review several concepts regarding regularization techniques for inverse problems. We determine an analytical relationship between the two existing regularization approaches and show graphically similarities between them. Next, several realizations of permeability fields are obtained by the inversion of production data without any type of regularization criteria as well as applying each of the regularization techniques. We then perform a comparative analysis of the results obtained. These models are qualitatively compared with the true solution. Finally, recognizing the importance of the relative weighting of the regularization term and the data misfit, its optimal value is investigated. The regularization techniques studied here are distribution is reconstructed using water-cut history from producing wells. This synthetic example addresses some of the key issues regarding the behavior of the solutions of the inverse problem. As a result of this study, a practical set of guidelines regarding several factors which affect the uniqueness of the inverse problem is presented.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Cobenas, R. H. (2012). A closer look at non-uniqueness during dynamic data integration. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C63

Chicago Manual of Style (16^th Edition):

Cobenas, Rafael H. “A closer look at non-uniqueness during dynamic data integration.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C63.

MLA Handbook (7^th Edition):

Cobenas, Rafael H. “A closer look at non-uniqueness during dynamic data integration.” 2012. Web. 11 Apr 2021.

Vancouver:

Cobenas RH. A closer look at non-uniqueness during dynamic data integration. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C63.

Council of Science Editors:

Cobenas RH. A closer look at non-uniqueness during dynamic data integration. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C63

Texas A&M University

6. Eide, Karen. Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E346

► The technique that uses microorganisms to improve oil production in petroleum reservoirs is known as microbial enhanced oil recovery (MEOR). Aerobic microbial enhanced oil recovery… (more)

▼ The technique that uses microorganisms to improve oil production in petroleum reservoirs is known as microbial enhanced oil recovery (MEOR). Aerobic microbial enhanced oil recovery is a method which is based on stimulating indigenous oil degrading bacteria by introducing oxygen (air) and nutrients into the injection water in an existing water flood. The primary emphasis is to promote biological growth in the oil/ water interface, which reduces the interfacial tension and mobilizes the oil. This process is proven to work in laboratory studies, and successful field tests have been reported in USSR. A pilot test on AMEOR has been initiated in the North Brock field in Oklahoma. The treatment, which consists of a continuous injection of air together with an appropriate nutrient supply, has been going on for seven months. So far no increase in oil production has been observed in the full field scale. However, well tests performed on each production well show an increase in oil production from two wells. This increase does not have any effect on the total oil production due to decline periods in the other wells. The most positive observation in the field test is an increase in the differential pressure observed right after the start of oxygen injection. This may be a result of reduced permeability to water in the oil bank, indicating an oil mobilization process in the reservoir. The same effect has also been observed in the laboratory core studies. The process is also proven to be time dependent and independent of the number of pore volumes flooded. It is concluded that it is too early in the process to experience any incremental oil production. The pressure increase may indicate that a mobilization process is going on and that it will only be a matter of time before any additional oil will be experienced in the field. This research involves an analysis of the pilot study in the North Brock field, in addition to a description of the AMEOR technique, effects and limitations. A comparison to other conventional MEOR techniques is also given.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Eide, K. (2012). Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E346

Chicago Manual of Style (16^th Edition):

Eide, Karen. “Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E346.

MLA Handbook (7^th Edition):

Eide, Karen. “Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study.” 2012. Web. 11 Apr 2021.

Vancouver:

Eide K. Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E346.

Council of Science Editors:

Eide K. Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E346

Texas A&M University

7. Espinel Diaz, Arnaldo Leopoldo. A reservoir management strategy for multilayered reservoirs in eastern Venezuela.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E87

► A reservoir management strategy has been developed for a field located in eastern Venezuela. The field contains deep, high pressure, multilayer reservoirs. A thorough formation… (more)

▼ A reservoir management strategy has been developed for a field located in eastern Venezuela. The field contains deep, high pressure, multilayer reservoirs. A thorough formation evaluation was accomplished using the log data, core data, PVT data, geologic data, well completion data and the production data. A reservoir simulation model was built to forecast reservoir performance for a variety of exploitation and well completion strategies. Reserve forecasts have been made using the reservoir model. The methodology applied in this research consists of eight tasks: 1) build a data base with existing data, 2) analyze the log and core data, 3) analyze the pressure and production data, 4) analyze the PVT data, 5) analyze the hydraulic fracture treatments, 6) build the reservoir model, 7) determine the possible reservoir management strategies, and 8) perform economic evaluations for the management strategies. While much of the data for the field studied was supplied by PDVSA, we did not receive all of the data we requested. For example, no pressure buildup data were available. When necessary, we used correlations to determine values for reservoir data that we were not supplied. In this research four formations were studied and characterized, determining porosity and permeability values. Also, fracture treatments were analyzed and a reservoir model was developed. Runs for black oil and volatile oil were performed. The results show that the upper zones are the most prospective areas, but fracture treatments must be performed to reduce the damage on the sand face. Lower formations (Cretaceous) have a lower permeability value, but high OOIP that justify performing fracture treatments and completing this zone. Economics were developed to support this conclusion. Optimum well spacing was calculated showing that 960 acres is the optimum well spacing, but also that 640 acres can be maintained for all the reservoirs and dual completions can be performed, first hydraulic fracturing and completing the Cretaceous formation, and then, completing any upper zone. Reservoir simulation results show that up to 31% of OOIP may be incrementally recovered by hydraulic fracturing the Cretaceous formation and 10 or less from the upper zones.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Espinel Diaz, A. L. (2012). A reservoir management strategy for multilayered reservoirs in eastern Venezuela. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E87

Chicago Manual of Style (16^th Edition):

Espinel Diaz, Arnaldo Leopoldo. “A reservoir management strategy for multilayered reservoirs in eastern Venezuela.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E87.

MLA Handbook (7^th Edition):

Espinel Diaz, Arnaldo Leopoldo. “A reservoir management strategy for multilayered reservoirs in eastern Venezuela.” 2012. Web. 11 Apr 2021.

Vancouver:

Espinel Diaz AL. A reservoir management strategy for multilayered reservoirs in eastern Venezuela. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E87.

Council of Science Editors:

Espinel Diaz AL. A reservoir management strategy for multilayered reservoirs in eastern Venezuela. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E87

Texas A&M University

8. Florez, Alberto. A parameter sensitivity analysis using an EOS for optimal characterization of Cupiagua reservoir fluids.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-F59

► : : Issued also on microfiche from Lange Micrographics. Cupiagua field is located in the foothill belt of the Llanos basin in eastern Colombia. This… (more)

▼ : : Issued also on microfiche from Lange Micrographics. Cupiagua field is located in the foothill belt of the Llanos basin in eastern Colombia. This field has large reserves of retrograde gas in the Mirador (Tertiary), Barrio, and Guadalupe (Cretaceous) formations that are typically beyond 12,000 ft with in-situ pressures and temperatures higher than 5,500 psi and [], respectively. The Cupiagua hydrocarbon system contains favorable thermodynamic factors (composition, pressure, and temperature) for a gas injection process to improve the hydrocarbon recovery. To carry out this process successfully, we need a good characterization of the reservoir hydrocarbons to predict thermodynamic fluid behavior. Further, this characterization is to be used in a compositional simulation to predict the distribution of the fluid saturation and pressure through the reservoir. In this work, the characterization of the Cupiagua fluid system was accomplished by use of the modified Pang-Robinson equation of state (PR-EOS). Experimental data from four welts at difference depth were used. The characterization procedure developed for this purpose includes defining EOS properties, pseudoization, mixing rules, and tuning the molecular weight of the heavy fraction, weighting factors, and regression of the Da and Db parameters of the EOS. Schemes of 10 and 7 pseudocomponents were used to calculate the EOS parameters. A unique description for surface and reservoir conditions was used in the simulation process. The results were compared with the experimental data to find the best predictor scheme. We found that a good match of experimental data was obtained for both the 10-and J-pseudocomponent schemes. The 10-psudocomponent scheme was selected to illustrate the matching process between lab data and EOS data. A compositional con-elation of the composition with depth was found and used to extrapolate the composition throughout the reservoir. Finally, a three-dimensional composition simulation was carried out using the both schemes. The 10-pseucomponent scheme showed good results and high stability during the entire simulation. The 7-pseudocomponent scheme presented high instability at higher rates of production, and the computing time was not improved substantially with respect to the computing time of the 10-pseudocomponent scheme.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Florez, A. (2012). A parameter sensitivity analysis using an EOS for optimal characterization of Cupiagua reservoir fluids. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-F59

Chicago Manual of Style (16^th Edition):

Florez, Alberto. “A parameter sensitivity analysis using an EOS for optimal characterization of Cupiagua reservoir fluids.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-F59.

MLA Handbook (7^th Edition):

Florez, Alberto. “A parameter sensitivity analysis using an EOS for optimal characterization of Cupiagua reservoir fluids.” 2012. Web. 11 Apr 2021.

Vancouver:

Florez A. A parameter sensitivity analysis using an EOS for optimal characterization of Cupiagua reservoir fluids. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-F59.

Council of Science Editors:

Florez A. A parameter sensitivity analysis using an EOS for optimal characterization of Cupiagua reservoir fluids. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-F59

Texas A&M University

9. Garcia, Ivette. Different methodologies for obtaining a permeability distribution in the Misoa Formation, Venezuela.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-G364

► Two methodologies have been applied for evaluating formation permeability using log and core data. One methodology is based on a modified Kozeny-Carmen equation and the… (more)

▼ Two methodologies have been applied for evaluating formation permeability using log and core data. One methodology is based on a modified Kozeny-Carmen equation and the concept of mean hydraulic radius. The other methodology involves a permeability correlation as a function of porosity and grain diameter based on systematic packing. These two methodologies have been used to determine a permeability profile in the Misoa Formation, Venezuela. Formation permeability controls the strategies involving well completion, well stimulation and reservoir management. The tools we normally use to estimate values of permeability are logs, cores, well tests and production data. One can also use seismic data to assist in computing the permeability distribution between the wells. The most economic method to evaluate formation permeability will usually be from well logs. In this research, we used logs and special core analyses to determine the permeability correlation in a specific reservoir located in the VLE-196 area of Block V in Lake Maracaibo, Venezuela. The VLE-1 96 area has production from the B, C2, C3, C4 and C5 reservoirs. The data from logs, cores, well tests and production are plentiful, but these data have never been correlated in an effort to compute the permeability distribution. Knowledge of the permeability distribution in the "C" sand reservoirs in the VLE-196 area would be of significant benefit to the operating company, P.D.V.S.A. In this research, I applied and compared the Amaefule et aL and Berg methodologies with the standard regression method for correlating permeability. I used log and special core data from two wells, VLE 1063 and VLE 677, in the VLE-1 96 area. The final step was to propose the best permeability correlation in the C-4 and C-5 sands in the VLE-1 96 area. According with the results combining the Amaefule method with a strong statistic analyses give a good permeability correlation in the C-4 and C-5 intervals. Reservoir Rock Properties", GCAGS Trans. (1970) 20, 303. Amaefule, JO., Altunbay, M, Tiab, D., Kersey, D.G., and Keelan, D.K.: 'Enhanced Reservoir Description: Using Core and Log Data to Identify 1-iydraulic (Flow) Units and Predict Permeability in Uncored Intervals/Wells", paper SPE 26436 presented at the 68th Annual Technical Conference and Exhibition, Houston, October 3-6, 1993.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Garcia, I. (2012). Different methodologies for obtaining a permeability distribution in the Misoa Formation, Venezuela. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-G364

Chicago Manual of Style (16^th Edition):

Garcia, Ivette. “Different methodologies for obtaining a permeability distribution in the Misoa Formation, Venezuela.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-G364.

MLA Handbook (7^th Edition):

Garcia, Ivette. “Different methodologies for obtaining a permeability distribution in the Misoa Formation, Venezuela.” 2012. Web. 11 Apr 2021.

Vancouver:

Garcia I. Different methodologies for obtaining a permeability distribution in the Misoa Formation, Venezuela. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-G364.

Council of Science Editors:

Garcia I. Different methodologies for obtaining a permeability distribution in the Misoa Formation, Venezuela. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-G364

Texas A&M University

10. Haase, Dalan David. An investigation of the effectiveness of anhydrous mud acid to remove damage in sandstone formations.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H333

► The goal of this experimental research was to determine the reactivity of anhydrous mud acid with clay minerals present in sandstone formations and its ability… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Haase, D. D. (2012). An investigation of the effectiveness of anhydrous mud acid to remove damage in sandstone formations. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H333

Chicago Manual of Style (16^th Edition):

Haase, Dalan David. “An investigation of the effectiveness of anhydrous mud acid to remove damage in sandstone formations.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H333.

MLA Handbook (7^th Edition):

Haase, Dalan David. “An investigation of the effectiveness of anhydrous mud acid to remove damage in sandstone formations.” 2012. Web. 11 Apr 2021.

Vancouver:

Haase DD. An investigation of the effectiveness of anhydrous mud acid to remove damage in sandstone formations. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H333.

Council of Science Editors:

Haase DD. An investigation of the effectiveness of anhydrous mud acid to remove damage in sandstone formations. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H333

Texas A&M University

11. Haland, Kjersti. Evaluation of hydrogen sulfide concentrations in Norwegian reservoir fluids.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H35

► Knowledge of the hydrogen sulfide content in produced hics. petroleum fluids is important for planning of [HaS] control measures and for material selection. The Norwegian… (more)

▼ Knowledge of the hydrogen sulfide content in produced hics. petroleum fluids is important for planning of [HaS] control measures and for material selection. The Norwegian Continental Shelf is known for producing sweet crude oils, and [HaS] has caused few problems due to low concentrations, usually below 10ppm. However, as the exploration was moved north into the Norwegian Sea, deeper exploration welts were drilled and an increase in the HZS concentrations were detected. Well test data clearly indicate that the concentration of HZS increases with depth of burials i.e. with increasing reservoir temperature. This thesis analyzes data from a large number of exploration welts drilled in sandstone reservoirs on the Norwegian Continental Shelf. Drill stem test of a duration of at least 10 hours are needed to get a stable and reliable level of [HaS] in the produced gas. However, the trend in the oil industry is that fewer exploration wells are tested and often only lifeline samples of reservoir fluids are available. Additionally, fast track field developments often require good estimates of expected [HaS] very early. The male objective was to establish an empirical correlation between [HaS] concentration in the reservoir fluids and the reservoir temperature. The amount of hydrogen sulfide generated by thermal cracking was believed to exibit an exponential relationship with reservoir temperature. A plot of the logarithm of the [HaS] concentration versus the inverse of the reservoir temperature was found to be linear to a good approximation. This indicates an exponential relationship between hydrogen sulfide and reservoir temperature. A certain scatter in the data can be explained by uncertainty in the [HZS] field measurements and by differences in loss and removal of [HZS] in the reservoirs, due to the presence of iron and water. Several empirical correlations were developed in this work allowing a reasonably accurate estimate of the expected [HZS] in produced gas. One is based on the assumed exponential relationship between [HZS] and reservoir temperature, the others include additional fluid parameters. This contribution is considered of particular importance for planning [HZS] control strategies and for production management.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Haland, K. (2012). Evaluation of hydrogen sulfide concentrations in Norwegian reservoir fluids. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H35

Chicago Manual of Style (16^th Edition):

Haland, Kjersti. “Evaluation of hydrogen sulfide concentrations in Norwegian reservoir fluids.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H35.

MLA Handbook (7^th Edition):

Haland, Kjersti. “Evaluation of hydrogen sulfide concentrations in Norwegian reservoir fluids.” 2012. Web. 11 Apr 2021.

Vancouver:

Haland K. Evaluation of hydrogen sulfide concentrations in Norwegian reservoir fluids. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H35.

Council of Science Editors:

Haland K. Evaluation of hydrogen sulfide concentrations in Norwegian reservoir fluids. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-H35

Texas A&M University

12. Jensen, Marianne. Productivity index and field behavior: a case study.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-J464

► This study is an investigation of different factors' phics. influence on the productivity index and its behavior. The objectives of this research are (1) to… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Jensen, M. (2012). Productivity index and field behavior: a case study. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-J464

Chicago Manual of Style (16^th Edition):

Jensen, Marianne. “Productivity index and field behavior: a case study.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-J464.

MLA Handbook (7^th Edition):

Jensen, Marianne. “Productivity index and field behavior: a case study.” 2012. Web. 11 Apr 2021.

Vancouver:

Jensen M. Productivity index and field behavior: a case study. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-J464.

Council of Science Editors:

Jensen M. Productivity index and field behavior: a case study. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-J464

Texas A&M University

13. El-Ahmady, Mohamed Hamed. Non-uniqueness problem in estimating original gas in place.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-E41

► This thesis demonstrates the problem of non-uniqueness in estimating Original Gas in Place of gas reservoirs using the material balance technique. The presence of this… (more)

▼ This thesis demonstrates the problem of non-uniqueness in estimating Original Gas in Place of gas reservoirs using the material balance technique. The presence of this non-uniqueness problem can cause an overestimation of the Original Gas in Place and a negligence of the effect of a considerable encroaching aquifer that could be thought not to exist. This study shows several examples for synthetic gas reservoir/aquifer systems that are modeled mathematically, then programmed, to simulate the performance of these systems. Aquifer analytical models for linear and radial shapes were used to calculate for the effect of the water encroachment. It is shown that the performance plots for material balance techniques (p/z technique and Havlena-Odeh technique) show a misleading behavior that can be misinterpreted to be of a closed (volumetric) reservoir, while actually it is for a water-drive gas reservoir of much less Original Gas in Place. Two models for reservoir/aquifer systems were developed to illustrate the non-uniqueness performance. In the first model, which is the forward model, we input the rate schedule and we obtain the pressure performance throughout the production history. In the second model, which is the inverse model, we assume a fake overestimated Original Gas in Place (G'), which implicitly defines a specific cumulative production/ pressure history of a linear p/z plot. The output of the inverse model is a unique production rate schedule for a synthetic case of a water-drive gas reservoir. If we produce our synthetic case using this rate schedule, we will obtain an exact performance on material balance plots of what historically reservoir engineers believed to be a closed reservoir. The extrapolation of the plots in this latter case show a false overestimated Original Gas in Place (G'). In conclusion, we can say that under certain circumstances, the material balance techniques for determining the Original Gas in Place of gas reservoirs can exhibit a clear non-uniqueness problem.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

El-Ahmady, M. H. (2012). Non-uniqueness problem in estimating original gas in place. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-E41

Chicago Manual of Style (16^th Edition):

El-Ahmady, Mohamed Hamed. “Non-uniqueness problem in estimating original gas in place.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-E41.

MLA Handbook (7^th Edition):

El-Ahmady, Mohamed Hamed. “Non-uniqueness problem in estimating original gas in place.” 2012. Web. 11 Apr 2021.

Vancouver:

El-Ahmady MH. Non-uniqueness problem in estimating original gas in place. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-E41.

Council of Science Editors:

El-Ahmady MH. Non-uniqueness problem in estimating original gas in place. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-E41

Texas A&M University

14. Ferguson,Mark Anthony. Further experimental studies of steam-propane injection to enhance recovery of Morichal oil.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-F465

► In 1998-1999, experimental research was conducted by Goite at Texas A&M University into steam-propane injection to enhance oil recovery from the Morichal field, Venezuela. Goite's… (more)

▼ In 1998-1999, experimental research was conducted by Goite at Texas A&M University into steam-propane injection to enhance oil recovery from the Morichal field, Venezuela. Goite's results showed that, compared with steam injection alone, steam-propane injection accelerated oil production by as much as 23 % pore volume of steam injected (cold-water equivalent). The apparatus and procedure used in this study have been improved. Steam injection rate was kept constant at 5 cc/min (cold-water equivalent) for all runs. Four thermocouples were placed along the longitudinal axis of the cell to measure temperature profiles during injection. A new, more efficient method was developed to break emulsion in the produced sample. For four of the eight runs, consistent operating conditions were obtained by use of superheated steam, cell pressure of 50 psig, and identical insulation. Eight experimental runs were made in which the propane:steam mass ratios used were 0:100 (steam only), 1:100, 2.5:100, and 5:100. A run using 5:100 nitrogen: steam mass ratio was also made. The main findings of this research (derived from four runs with consistent operating conditions) are as follows. First, the propane:steam mass ratio of 5:100 accelerated the start and peak of oil production by 20 % and 13 % pore volume steam injected (cold-water equivalent), compared to steam injection alone. Second, oil recoveries for practical purposes are similar in all cases, 63 % - 70 % OOIP if average high and low values are taken. Third, the start of production is practically the same for 0:100 and 1:100 propane:steam ratio and for 5:100 nitrogen: steam ratio. In the latter case, the production peak is higher due to additional drive from nitrogen injection. Fourth, oil production acceleration in the 5:100 propane:steam case is probably caused by dry distillation in which light fractions of the oil partition into and are carried by the injected propane to lower the viscosity of the oil ahead of the steam front. Last, convective heat transfer at any of these low (5:100) ratios appears to be of secondary importance.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Anthony, F. (2012). Further experimental studies of steam-propane injection to enhance recovery of Morichal oil. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-F465

Chicago Manual of Style (16^th Edition):

Anthony, Ferguson,Mark. “Further experimental studies of steam-propane injection to enhance recovery of Morichal oil.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-F465.

MLA Handbook (7^th Edition):

Anthony, Ferguson,Mark. “Further experimental studies of steam-propane injection to enhance recovery of Morichal oil.” 2012. Web. 11 Apr 2021.

Vancouver:

Anthony F. Further experimental studies of steam-propane injection to enhance recovery of Morichal oil. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-F465.

Council of Science Editors:

Anthony F. Further experimental studies of steam-propane injection to enhance recovery of Morichal oil. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-F465

Texas A&M University

15. Gutierrez, Fernando A. Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-G87

► Tests were conducted to evaluate the effect of lubricants in formation damage. Two types of lubricants were tested along with two types of drill-in fluids.… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Gutierrez, F. A. (2012). Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-G87

Chicago Manual of Style (16^th Edition):

Gutierrez, Fernando A. “Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-G87.

MLA Handbook (7^th Edition):

Gutierrez, Fernando A. “Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells.” 2012. Web. 11 Apr 2021.

Vancouver:

Gutierrez FA. Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-G87.

Council of Science Editors:

Gutierrez FA. Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-G87

Texas A&M University

16. Cerutti, Andres Enrique. Coreflood experimental study of steam displacement.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C434

► The main objective of this study was to verify experimentally whether or not a Buckley-Leverett shock front exists when steam displaces oil in a porous… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Cerutti, A. E. (2012). Coreflood experimental study of steam displacement. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C434

Chicago Manual of Style (16^th Edition):

Cerutti, Andres Enrique. “Coreflood experimental study of steam displacement.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C434.

MLA Handbook (7^th Edition):

Cerutti, Andres Enrique. “Coreflood experimental study of steam displacement.” 2012. Web. 11 Apr 2021.

Vancouver:

Cerutti AE. Coreflood experimental study of steam displacement. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C434.

Council of Science Editors:

Cerutti AE. Coreflood experimental study of steam displacement. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-1997-THESIS-C434

Texas A&M University

17. Moreno Romero, Fidel Enrique. Experimental investigation of sand consolidation using high-temperature alkaline solution.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-M678

► An experimental study was conducted to better understand the sand consolidation process under high-temperature alkaline solution. Wilmington Tar sand samples were successfully consolidated in the… (more)

▼ An experimental study was conducted to better understand the sand consolidation process under high-temperature alkaline solution. Wilmington Tar sand samples were successfully consolidated in the laboratory using high-temperature (250-260⁰C) solution of sodium carbonate (pH 11-12). The sample was placed in a vertical 18 in. long aluminum cylindrical cell with an ID of 1.5 in.. The top half of the cell was thermally insulated while the bottom half was cooled. Hot alkaline solution was injected at 20 ml/min for 3-4 hours at the top of the cell and liquid produced at the bottom of the cell. After each experiment, the cell contents were removed and analyzed to determine if sand consolidation occurred. Both aggregates of sand grains and sectioned and polished epoxy-mounted sand grains were examined and analyzed using an electron microprobe to determine any change in shape, size, or composition of the sand pack and precipitation and growth of secondary phases. To better understand the process, experiments were subsequently conducted using samples of pure quartz, pure feldspar, and a 50:50 (by weight) mixture of quartz and feldspar. In each case, both varied 20-40 mesh and 50-250 mesh grain size samples were used. For the 20-40 mesh cases, zeolites and a mixture of amorphous silica and sodium carbonate were deposited on grain surfaces but were insufficient to cause overall sand consolidation. However, when a finer, poorly sorted (50-250 mesh) 50:50 mixture of feldspar and quartz was used, sand consolidation was obtained in 2.5 hours. At the top, hotter part of the cell, equant and acicular zeolite crystals (sodium aluminum silicates) weakly bound the sand grains. At the bottom and cooler part of the cell, the sand grains were strongly bound by a mixture of amorphous silica and sodium carbonate. Results to-date indicate that both zeolite and silica may be cementing agents, the grain-bonding strength depending on the grain surface area. This investigation is part of an ongoing research. The temperature, injection rate, and pH of the alkaline solution, treating time and "soaking period" are considered important process parameters that need to be further investigated.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Moreno Romero, F. E. (2012). Experimental investigation of sand consolidation using high-temperature alkaline solution. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-M678

Chicago Manual of Style (16^th Edition):

Moreno Romero, Fidel Enrique. “Experimental investigation of sand consolidation using high-temperature alkaline solution.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-M678.

MLA Handbook (7^th Edition):

Moreno Romero, Fidel Enrique. “Experimental investigation of sand consolidation using high-temperature alkaline solution.” 2012. Web. 11 Apr 2021.

Vancouver:

Moreno Romero FE. Experimental investigation of sand consolidation using high-temperature alkaline solution. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-M678.

Council of Science Editors:

Moreno Romero FE. Experimental investigation of sand consolidation using high-temperature alkaline solution. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-M678

Texas A&M University

18. Roco, Craig Emmitt. Reservoir characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field-federal waters, offshore California.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-R625

► This thesis presents the characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field, which lies seven miles offshore of Ventura County,… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Roco, C. E. (2012). Reservoir characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field-federal waters, offshore California. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-R625

Chicago Manual of Style (16^th Edition):

Roco, Craig Emmitt. “Reservoir characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field-federal waters, offshore California.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-R625.

MLA Handbook (7^th Edition):

Roco, Craig Emmitt. “Reservoir characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field-federal waters, offshore California.” 2012. Web. 11 Apr 2021.

Vancouver:

Roco CE. Reservoir characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field-federal waters, offshore California. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-R625.

Council of Science Editors:

Roco CE. Reservoir characterization of the Upper and Lower Repetto reservoirs of the Santa Clara field-federal waters, offshore California. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-R625

Texas A&M University

19. Serrano, Gerardo Enrique. Laboratory tests, statistical analysis and correlations for regained permeability and breakthrough time in unconsolidated sands for improved drill-in fluid cleanup practices.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-S476

► Empirical models for estimating the breakthrough time and regained permeability for selected nondamaging drill-in fluids (DIF's) give a clear indication of formation damage and proper… (more)

▼ Empirical models for estimating the breakthrough time and regained permeability for selected nondamaging drill-in fluids (DIF's) give a clear indication of formation damage and proper cleanup treatments for reservoir conditions analyzed in this study. We determined values of breakthrough time and regained permeability for common polymer-carbonate and sized-salt/saturated brine DIF's for a range at reservoir properties including temperature, drill solids content, and percent of acid in the cleanup treatment. We chose these DIF's because they form tight, thin filtercakes that control fluid leakoff and afford more complete wellbore cleanup properties than standard drilling muds, and we chose reservoir properties that could be varied and measured. Beginning with a large database of 101 tests with 8 independent variables such as type of drill-in fluid, temperature, screen type, presence of gravel pack, formation type, type of drill solids, concentration of drill solids, and cleanup treatments, we analyzed the importance of each variable. After that, we identified the independent variables we were taking into account during this research. Those variables were temperature, drill solids content, and concentration of hydrochloric acid in the cleanup treatment. Then we generated a matrix for each set of experiments that allowed us to organize and measure the conditions we were looking for, regained permeability and breakthrough time. In measuring the regained permeability, we used a linear-flow cell apparatus. In measuring the breakthrough time that particular cleaning procedures take to flow across the filter cake, we used a ceramic disc cell apparatus. We used statistical software to select properties, formation, and diagnostics of the models and to develop relationships among the properties of the DIF's. We developed four new empirical models for estimating the breakthrough time and regained permeability in polymer carbonate and sized salt. High correlations resulted with R² values between 0.851 and 0.986 corroborated by close values of adjusted R-square and low P-values give validity to the correlations found. This technique gives a broad overview of the formation damage as well as the proper cleanup treatment for similar conditions presented in the field.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Serrano, G. E. (2012). Laboratory tests, statistical analysis and correlations for regained permeability and breakthrough time in unconsolidated sands for improved drill-in fluid cleanup practices. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-S476

Chicago Manual of Style (16^th Edition):

Serrano, Gerardo Enrique. “Laboratory tests, statistical analysis and correlations for regained permeability and breakthrough time in unconsolidated sands for improved drill-in fluid cleanup practices.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-S476.

MLA Handbook (7^th Edition):

Serrano, Gerardo Enrique. “Laboratory tests, statistical analysis and correlations for regained permeability and breakthrough time in unconsolidated sands for improved drill-in fluid cleanup practices.” 2012. Web. 11 Apr 2021.

Vancouver:

Serrano GE. Laboratory tests, statistical analysis and correlations for regained permeability and breakthrough time in unconsolidated sands for improved drill-in fluid cleanup practices. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-S476.

Council of Science Editors:

Serrano GE. Laboratory tests, statistical analysis and correlations for regained permeability and breakthrough time in unconsolidated sands for improved drill-in fluid cleanup practices. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2000-THESIS-S476

Texas A&M University

20. Aguilar Zurita, Rafael A. An efficient tuning strategy to calibrate cubic EOS for compositional simulation.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A34

► A new strategy for preparing an equation of state for use in compositional simulation is presented. The strategy comprises three major steps: extending the plus… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Aguilar Zurita, R. A. (2012). An efficient tuning strategy to calibrate cubic EOS for compositional simulation. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A34

Chicago Manual of Style (16^th Edition):

Aguilar Zurita, Rafael A. “An efficient tuning strategy to calibrate cubic EOS for compositional simulation.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A34.

MLA Handbook (7^th Edition):

Aguilar Zurita, Rafael A. “An efficient tuning strategy to calibrate cubic EOS for compositional simulation.” 2012. Web. 11 Apr 2021.

Vancouver:

Aguilar Zurita RA. An efficient tuning strategy to calibrate cubic EOS for compositional simulation. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A34.

Council of Science Editors:

Aguilar Zurita RA. An efficient tuning strategy to calibrate cubic EOS for compositional simulation. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A34

Texas A&M University

21. Alvarez Vera, Cesar. Effects of non-Darcy flow on pressure buildup analysis of hydraulically fractured gas reservoirs.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A4592

► Conventional well-testing techniques are commonly used to evaluate pressure transient tests of hydraulically fractured wells to estimate values such as formation permeability, fracture length, and… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Alvarez Vera, C. (2012). Effects of non-Darcy flow on pressure buildup analysis of hydraulically fractured gas reservoirs. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A4592

Chicago Manual of Style (16^th Edition):

Alvarez Vera, Cesar. “Effects of non-Darcy flow on pressure buildup analysis of hydraulically fractured gas reservoirs.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A4592.

MLA Handbook (7^th Edition):

Alvarez Vera, Cesar. “Effects of non-Darcy flow on pressure buildup analysis of hydraulically fractured gas reservoirs.” 2012. Web. 11 Apr 2021.

Vancouver:

Alvarez Vera C. Effects of non-Darcy flow on pressure buildup analysis of hydraulically fractured gas reservoirs. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A4592.

Council of Science Editors:

Alvarez Vera C. Effects of non-Darcy flow on pressure buildup analysis of hydraulically fractured gas reservoirs. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-A4592

Texas A&M University

22. Barbuceanu, Nicolae. Performance improvement of Gas-Liquid Cylindrical Cyclone separator using different design for tangential inlet.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-B35

► The concept of compact separation is attractive in a number of operating environments. These include offshore and arctic operations, where both space and weight are… (more)

▼ The concept of compact separation is attractive in a number of operating environments. These include offshore and arctic operations, where both space and weight are at a premium, and downhole processing where space is very limited. Compact separators often rely on centrifugal forces to enhance the separation process and are therefore highly dependent on inlet geometry. This paper investigates expanding the operational envelope of a compact Gas-Liquid Cylindrical Cyclone separator through the use of a novel inlet, which can be easily altered to respond to changing well conditions. To demonstrate the importance of inlet geometry, historical production from the Gloyd-Mitchell zone of the Rodessa Field in Louisiana was examined over a 40-month period. As in most oil field production, there were significant changes in the water cut and GOR. This field data clearly shows that a compact separator equipped with single inlet geometry is not capable of performing effectively over the wide range of conditions exhibited in a typical oil field. This thesis considers the hydrodynamics of the separator inlet. Three different inlet geometries were investigated through the use of a changeable inlet sleeve. New experimental data were acquired utilizing a 7.62-cm I.D compact separator, which was 3.0 m in height. The effect of inlet geometry on separator performance was investigated over a wide range of flow conditions. Fluid viscosities from 1-12 cp and the effect of fluid level within the separator were also examined. The results indicate that the operational envelope for liquid carry-over and gas carry-under can be expanded by more that 300% by altering the inlet to respond to changing field conditions. A new model is proposed to define the operational envelope. This approximate method is simple to calculate, and offers a good approximation for the operability area for gas-liquid cylindrical cyclone compact separator. This study shows that efficient operability of the gas-liquid cylindrical cyclone is obtained when tangential acceleration of the incoming gas-liquid mixture is 50 to100 times the acceleration of gravity (50-100 G's).

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Barbuceanu, N. (2012). Performance improvement of Gas-Liquid Cylindrical Cyclone separator using different design for tangential inlet. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-B35

Chicago Manual of Style (16^th Edition):

Barbuceanu, Nicolae. “Performance improvement of Gas-Liquid Cylindrical Cyclone separator using different design for tangential inlet.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-B35.

MLA Handbook (7^th Edition):

Barbuceanu, Nicolae. “Performance improvement of Gas-Liquid Cylindrical Cyclone separator using different design for tangential inlet.” 2012. Web. 11 Apr 2021.

Vancouver:

Barbuceanu N. Performance improvement of Gas-Liquid Cylindrical Cyclone separator using different design for tangential inlet. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-B35.

Council of Science Editors:

Barbuceanu N. Performance improvement of Gas-Liquid Cylindrical Cyclone separator using different design for tangential inlet. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-B35

Texas A&M University

23. Deghirmandjian, Odilia. Identification and characterization of Hydraulic Flow Units in the San Juan Formation, Orocual Field, Venezuela.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D44

► This thesis focuses on the integration of core and well log data in order to provide a petrophysical characterization of the Hydraulic Flow Units (HFU)… (more)

▼ This thesis focuses on the integration of core and well log data in order to provide a petrophysical characterization of the Hydraulic Flow Units (HFU) in the San Juan Formation, Orocual Field, Venezuela. We used three separate approaches to correlate/ integrate these data from Orocual Field. The first method uses the concept of Hydraulic Flow Units (HFU). The second method uses non-parametric transformation and regression, and the third method estimates permeability using polynomial and power law-type functions. We provide a comparison of these methods - and we believe that the HFU and non-parametric regression techniques give the most representative results. In this study we have core data for four wells and well log data for sixteen wells. The core permeability data were adjusted (in this work) to compensate for the Klinkenberg effect (a low pressure gas flow phenomena) and to relate porosity and permeability from laboratory to in-situ (net overburden stress) conditions. To model the stress correction we use the original reservoir pressure of 7470 psia and a two-point stress model. For well logs, we use a quality control method based on depth shift, depth match, environmental corrections, and core-log correlation. Finally, core permeability data were correlated to multiple well log suites (density, neutron, gamma ray, and resistivity). The HFU concept provides a deterministic approach for combining the geological attributes with available petrophysical data to delineate the reservoir into "units" of similar fluid flow characteristics. The HFU method does not presume a relationship between variables. The non-parametric regression/transform technique is based on using variable transformations to generate relationship between dependent and independent variables. This iterative, non-parametric procedure is called the Alternating Conditional Expectation (or ACE) method. Additional deterministic models based on polynomial, power law, and modified power law relations are also used to estimate permeability. The methodologies demonstrated in this work can be applied to any reservoir system having a significant population of permeability measurements and well log data.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Deghirmandjian, O. (2012). Identification and characterization of Hydraulic Flow Units in the San Juan Formation, Orocual Field, Venezuela. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D44

Chicago Manual of Style (16^th Edition):

Deghirmandjian, Odilia. “Identification and characterization of Hydraulic Flow Units in the San Juan Formation, Orocual Field, Venezuela.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D44.

MLA Handbook (7^th Edition):

Deghirmandjian, Odilia. “Identification and characterization of Hydraulic Flow Units in the San Juan Formation, Orocual Field, Venezuela.” 2012. Web. 11 Apr 2021.

Vancouver:

Deghirmandjian O. Identification and characterization of Hydraulic Flow Units in the San Juan Formation, Orocual Field, Venezuela. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D44.

Council of Science Editors:

Deghirmandjian O. Identification and characterization of Hydraulic Flow Units in the San Juan Formation, Orocual Field, Venezuela. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D44

Texas A&M University

24. Diaz Franco, Jose Manuel. Simulation study to investigate development options for a super-heavy oil reservoir.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D5304

► A reservoir simulation study was performed on a heavy oil reservoir with the main objective of evaluating possible development options beyond the existing cold production… (more)

▼ A reservoir simulation study was performed on a heavy oil reservoir with the main objective of evaluating possible development options beyond the existing cold production method. The 206-acre area simulated - part of a significantly larger oil accumulation - lies about 3000 ft. ss. and has a gross thickness of 560 ft. The simulated area contains 120 MMSTB oil of 9° API gravity with in situ viscosity of 6,000 cp. Production began in 1992 with the reservoir being drained by one vertical well, one slanted well and one horizontal well. The simulation study was conducted in a systematic manner using two types of commercial reservoir simulators to minimize computational time. For history matching the cold production period and forecasting of cold production cases, a black oil simulator was used (ECLIPSE 100). A fairly satisfactory match of the production and pressure data was obtained which required an analytical aquifer to be attached to the northern part of the reservoir. For thermal EOR cases, the oil was simulated as a hydrocarbon consisting of three pseudo components. These cases were run using a thermal compositional simulator (ECLIPSE 300). Simulation results indicate oil recovery, for the area developed by the existing horizontal well and two new horizontal wells, to be as follows. For cold production, the oil recovery amounts to 13% of original-oil-in-place (OOIP). With cyclic steam injection, the recovery factor is slightly increased to 15% OOIP. However, with steam flooding -utilizing the new horizontal wells as injectors - the recovery factor is significantly increased to 22% OOIP. Steam flooding is evidently superior to cyclic steam injection primarily due to the fact that the reservoir is pressurized in the former EOR method and not in the latter, and to the fact that cyclic steam injection is more a near-wellbore thermal stimulation process as opposed to a more reservoir-wide heating process under steam flooding. Finally, with steam-propane injection (at a constant steam:propane mass ratio of 100:5), the oil recovery factor is further increased to 26% OOIP. Simulation results indicate this EOR method creates a more favorable distribution of heat in the reservoir, thus better sweep efficiency and reduction in produced water cut. Selection of development options to be implemented would depend on the economics of each case. Economic evaluation of the various cases has not been covered in the thesis and is best done by the operator of the field.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Diaz Franco, J. M. (2012). Simulation study to investigate development options for a super-heavy oil reservoir. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D5304

Chicago Manual of Style (16^th Edition):

Diaz Franco, Jose Manuel. “Simulation study to investigate development options for a super-heavy oil reservoir.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D5304.

MLA Handbook (7^th Edition):

Diaz Franco, Jose Manuel. “Simulation study to investigate development options for a super-heavy oil reservoir.” 2012. Web. 11 Apr 2021.

Vancouver:

Diaz Franco JM. Simulation study to investigate development options for a super-heavy oil reservoir. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D5304.

Council of Science Editors:

Diaz Franco JM. Simulation study to investigate development options for a super-heavy oil reservoir. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-D5304

Texas A&M University

25. Falla Ramirez, Jorge H. Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F36

► Advancements in deepwater drilling have necessitated the use of more specialized reservoir drill-in fluids (RDIF). These RDIFs must exhibit unique rheological properties while minimizing formation… (more)

▼ Advancements in deepwater drilling have necessitated the use of more specialized reservoir drill-in fluids (RDIF). These RDIFs must exhibit unique rheological properties while minimizing formation damage. Xanthan gum biopolymer is generally used as a primary viscosifier in RDIFs. In high salinity brines the high shear rate viscosity that xanthan gum provides can approach levels that could exceed the fracture gradient of the well. Therefore, it is important to maintain a xanthan gum concentration that keeps the equivalent circulating density at a modest level. Reducing the xanthan gum level, however, compromises the hole cleaning properties that the low- shear-rate viscosity provides. Xanthan gum biopolymers are also associated with formation damage, which inhibits the flow of oil and gas during production. A new RDIF, which utilizes no xanthan gum biopolymer, has been recently developed. The new product uses a starch instead of polymer to develop rheological properties. This fluid will primarily be targeted for production zone drilling in highly deviated and horizontal wells. This research focused on filtercake cleanup and the reduced formation damage associated with this biopolymer-free fluid. The behavior of the polymer free fluid was analyzed developing tests at different temperatures, at different drill solids content, and with different treatment fluids. The laboratory methods used were a ceramic disc cell and a linear flow cell. The former will permit an analysis of the time that a certain cleaning treatment takes to flow through a filter cake. The latter simulates well completions in unconsolidated horizontal well reservoirs permitting the estimation of formation damage produced by drilling and completion fluids and the effectiveness of the cleaning treatment applied. Multivariate statistical analysis was performed with the experimental results obtained. Comparison with conventional RDIF data from polymer carbonate and sized salt fluids provided informative contrasts in performance.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Falla Ramirez, J. H. (2012). Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F36

Chicago Manual of Style (16^th Edition):

Falla Ramirez, Jorge H. “Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F36.

MLA Handbook (7^th Edition):

Falla Ramirez, Jorge H. “Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions.” 2012. Web. 11 Apr 2021.

Vancouver:

Falla Ramirez JH. Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F36.

Council of Science Editors:

Falla Ramirez JH. Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F36

Texas A&M University

26. Franquet Barbara, Javier Alejandro. 2-D discrete element modeling of unconsolidated sandstones.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F68

► In this work unconsolidated sands saturated with heavy oil were modeled using a discrete element numerical model, (DEM). The DEM code was built in Mathematica… (more)

▼ In this work unconsolidated sands saturated with heavy oil were modeled using a discrete element numerical model, (DEM). The DEM code was built in Mathematica ♭ programming language. The strain-stress behavior of biaxial tests using the code developed in this thesis is compared to the results of triaxial tests performed in cylindrical core samples of unconsolidated sandstones saturated with heavy oil. The discrete element model treats the sand as a two dimensional assembly of particles. The displacements and velocities of each particle are calculated in order to determine local rearrangements during deformation. The kinematics of the system is performed in small time steps where force and torque balance is calculated for each disk. Several grain forces are simulated in this DEM model when the unconsolidated sand, saturated with heavy oil, is under a deviatoric loading condition. The contact forces are modeled as spring and dashpot forces, and they are applied in the contact point in the normal and tangential directions. Friction viscous forces are included for linear displacements and for rotational movements. The viscous forces generated by the movements of very close neighborhood particles are also considered in the model. The DEM code is also capable of modeling capillary forces between grains when the assembly is considered partially saturated, and the interstitial liquid is filling the porous space as a discrete liquid bridge between particles. Four boundary walls surround the particle assembly. The bottom boundary is considered flat, frictionless, and static while the top boundary is a stress controlled wall. The other two vertical boundaries are under a confining distributive force, and these walls can be modeled as two parallel flexible boundaries or as a simple horizontal force condition distributed to the boundary particles. Compressibility and apparent Young's modulus are compared between the DEM results and the laboratory geomechanical data. This investigation is part of ongoing research to obtain the micro-mechanical parameters needed for future hydraulic fracture propagation studies in an unconsolidated formation impregnated with heavy oil.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Franquet Barbara, J. A. (2012). 2-D discrete element modeling of unconsolidated sandstones. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F68

Chicago Manual of Style (16^th Edition):

Franquet Barbara, Javier Alejandro. “2-D discrete element modeling of unconsolidated sandstones.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F68.

MLA Handbook (7^th Edition):

Franquet Barbara, Javier Alejandro. “2-D discrete element modeling of unconsolidated sandstones.” 2012. Web. 11 Apr 2021.

Vancouver:

Franquet Barbara JA. 2-D discrete element modeling of unconsolidated sandstones. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F68.

Council of Science Editors:

Franquet Barbara JA. 2-D discrete element modeling of unconsolidated sandstones. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-F68

Texas A&M University

27. Gan, Ronald Gunawan. A new p/z technique for the analysis of abnormally pressured gas reservoirs.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G36

► Drip tubing as a means of applying domestic wastewater to soil is increasing in use, especially in clayey soils that are unsuitable for traditional disposal… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Gan, R. G. (2012). A new p/z technique for the analysis of abnormally pressured gas reservoirs. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G36

Chicago Manual of Style (16^th Edition):

Gan, Ronald Gunawan. “A new p/z technique for the analysis of abnormally pressured gas reservoirs.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G36.

MLA Handbook (7^th Edition):

Gan, Ronald Gunawan. “A new p/z technique for the analysis of abnormally pressured gas reservoirs.” 2012. Web. 11 Apr 2021.

Vancouver:

Gan RG. A new p/z technique for the analysis of abnormally pressured gas reservoirs. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G36.

Council of Science Editors:

Gan RG. A new p/z technique for the analysis of abnormally pressured gas reservoirs. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G36

Texas A&M University

28. Ganpule, Sameer Vasant. Effects of flow paths on tight gas well performance.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G363

► This thesis is a collection of models, solutions and analysis equations or type curves useful in analyzing the production behavior of tight gas wells. Variety… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Ganpule, S. V. (2012). Effects of flow paths on tight gas well performance. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G363

Chicago Manual of Style (16^th Edition):

Ganpule, Sameer Vasant. “Effects of flow paths on tight gas well performance.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G363.

MLA Handbook (7^th Edition):

Ganpule, Sameer Vasant. “Effects of flow paths on tight gas well performance.” 2012. Web. 11 Apr 2021.

Vancouver:

Ganpule SV. Effects of flow paths on tight gas well performance. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G363.

Council of Science Editors:

Ganpule SV. Effects of flow paths on tight gas well performance. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G363

Texas A&M University

29. Guerra Camargo, Andrea M. Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G84

► Gas condensate reservoirs often exhibit a rapid decline in production with depletion. During early production, liquid dropout accumulates in the near wellbore area and this… (more)

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Guerra Camargo, A. M. (2012). Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G84

Chicago Manual of Style (16^th Edition):

Guerra Camargo, Andrea M. “Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G84.

MLA Handbook (7^th Edition):

Guerra Camargo, Andrea M. “Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production.” 2012. Web. 11 Apr 2021.

Vancouver:

Guerra Camargo AM. Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G84.

Council of Science Editors:

Guerra Camargo AM. Analysis of the dynamics of saturation and pressure close to the wellbore for condensate reservoirs as a tool to optimize liquid production. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-G84

Texas A&M University

30. Karpov, Alexandre Valerievich. Lisburne Formation fracture characterization and flow modeling.

Degree: MS, petroleum engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-K366

► Evaluation of fractured reservoirs for fluid flow and optimal well placement is often very complicated. In general, fractures enhance permeability and increase access to matrix… (more)

▼ Evaluation of fractured reservoirs for fluid flow and optimal well placement is often very complicated. In general, fractures enhance permeability and increase access to matrix surface, but their random aspects create difficulties for analysis and performance prediction. Each reservoir has unique aspects which require individual assessment. This study examined fracture properties in a part of the Carboniferous Lisburne Formation. Field study of outcrops yielded information on two sets of large-scale fractures (NNW and ENE orientations) from the lower Wahoo Limestone in the eastern Sadlerochit Mountains. Several statistical methods were used on these data to find appropriate models describing the megafracture properties. For NNW fracture height and ENE fracture spacing, the gamma model appears to adequately describe the distribution. NNW fracture spacing and ENE fracture height are lognormally distributed. Results of the statistical analyses were used as input for fracture set generation and modeling using "FracMan". Modeling different borehole orientations in the fractured domain revealed that horizontal wells with 60⁰ azimuth have an optimal trajectory, resulting in the maximum number and area of fracture connections. The orientation maximizing the number of fracture connections did not necessarily give the maximum area. Conductivity analysis showed that the fracture network is weakly anisotropic and above the percolation threshold. The fracture conductance is strongly dependent on the NNW fracture set; larger fractures influence fluid flow more than smaller fractures. Fracture strike and dip variability increased the system interconnectivity, but did not affect the optimal wellbore orientation. Incorporating ENE fracture termination against the NNW fractures decreased the system conductance and shifted the optimal wellbore trajectory towards the direction perpendicular to the NNW set. Reservoir engineering implications of this study include: guidelines for optimal wellbore orientations, the relative placement of injectors and producers along the bisectors between the two fracture sets, and the importance of including fracture terminations. Further work should investigate the influence of variations in fracture aperture and transmissivities, and drainage area, and extend the analysis to additional units of the Lisburne Group.

Subjects/Keywords: petroleum engineering.; Major petroleum engineering.

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APA (6^th Edition):

Karpov, A. V. (2012). Lisburne Formation fracture characterization and flow modeling. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-K366

Chicago Manual of Style (16^th Edition):

Karpov, Alexandre Valerievich. “Lisburne Formation fracture characterization and flow modeling.” 2012. Masters Thesis, Texas A&M University. Accessed April 11, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-K366.

MLA Handbook (7^th Edition):

Karpov, Alexandre Valerievich. “Lisburne Formation fracture characterization and flow modeling.” 2012. Web. 11 Apr 2021.

Vancouver:

Karpov AV. Lisburne Formation fracture characterization and flow modeling. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 11]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-K366.

Council of Science Editors:

Karpov AV. Lisburne Formation fracture characterization and flow modeling. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2001-THESIS-K366

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