<p> After primary and secondary recovery there is still oil remaining in the reservoir, so tertiary recovery is introduced. This is also known as EOR. Enhanced oil recovery has been widely used with different types of polymers. Algae polymer is a new development with its own advantages and limitations. In order to discover the economic potential of algae polymer, this paper focuses on the recovery factor of algae polymer and compares it with other published results.</p>

<p> A new mechanistic model is developed for computing flowing fluid temperature profiles in both conduits simultaneously for a continuous-flow gas-lift operation. The model assumes steady heat flow in the formation, as well as steady heat flow in the conduits. This work also presents a simplified algebraic solution to the analytic model, affording easy implementation in any existing program. An accurate fluid temperature computation should allow improved gas-lift design. </p><p> Comparisons of the Hasan model, Alves model, and the new model with data from the Thompson Well, O&rsquo;Connor Well, and Luo Wei Well show that the temperature profile given by the new model has a better accuracy than that of other models. </p><p> A sensitivity analysis was conducted with the new model. The results indicate that mass flow rate of oil and the tubing overall heat transfer coefficient are the main factors that influence the temperature distribution inside the tubing and that the mass flow rate of oil is the main factor affecting temperature distribution in the annulus. The annulus overall heat transfer coefficient and tubing overall heat transfer coefficient are the next significant factors. </p>

This thesis discusses the development and history of oil in the Middle East. The transportation and positions of various countries are presented.

No description available.

Thesis (M.S.)--Oregon State College, 1952. / "June 1952." Maps on four folded leaves in pocket. Bibliography: leaves 58-59. Also available on the World Wide Web.

Thesis (Ph. D.)--University of Tulsa, 1981. / Includes bibliographical references (leaves 101-102).

Thesis (Ph. D.)--University of Tulsa, 1980. / Vita. Includes bibliographical references (leaves 103-107).

West Delta Block 84 Field is located off the coast of Plaquemines Parish, Louisiana. The intent of this endeavor is to prove that the two of the reservoirs, the KE-1 and KF-1, form a single communicating reservoir, the KEKF-R1; that a waterflood into the KF-1 reservoir was ineffective; that oil reserves were bypassed; and that a portion of these bypassed oil reserves can be recovered without drilling new wells. Comparisons between pre-seismic and post-seismic geological interpretations were studied, a thorough volumetric analysis was performed with a subsequent material balance calculations and a reservoir computer simulation was performed. Once a history match was made, prediction studies were performed for both remaining primary reserves and for secondary reserves recoverable through a new water-flood design and implementation. There are many new insights on this reservoir as a result of this study. First, the KE-1 and the KF-1 reservoirs are indeed one communicating reservoir. The KF-1 waterflood was inefficient and resulted in bypassed oil pay. Bypassed oil may be recovered through several techniques. Based on prediction runs on BOAST, the best case scenario analyzed thus far without additional drilling is an additional 1,600,000 barrels of oil. This study indicates that a small amount of old technology, in the form of a resurrection of a waterflood and a small amount of new technology, in the form of the "Downhole Water Sink" (DWS) method will greatly increase the ultimate recovery of the lost reserves. This study has provided sufficient evidence and documentation to justify the need for additional research and study of this reservoir. More detailed recovery strategies should be prepared, the DWS technology should be studied in more detail and a more detailed grid should be prepared for the reservoir.

Researchers at Louisiana State University, LSU, have introduced several petrophysical models expressing the electric properties of shaly sands. These models, to be used for hydrocarbon detection, are based on the Waxman and Smits concept of supplementing the water conductivity with a clay counterions conductivity. The LSU models also utilize the Dual Water theory, which relates each conductivity term to a particular type of water, free and bound, each occupying a specific volume of the total pore space. The main difference between these models and the other shaly sand models is that the counterion conductivity is represented by a hypothetical sodium chloride electrolyte. This study introduces a modified version of early LSU models. This modified model eliminates a questionable assumption incorporated in all previous shaly sand models. Previous models use same formation resistivity factor for all terms in the model. The proposed model considers that the electric current follows the effective porosity path in the term representing the free electrolyte and follows the clay porosity path in the term representing bound water. The differentiation between the two paths is accomplished by using two different formation factors one in the free water and another in the bound water term of the model. It also used two different cementation exponents to express formation factors in terms of porosity. The validity of the new model was checked using cation exchange capacities measured on core samples and drill cuttings. Calculated cation exchange capacities display good agreement with the measured cation exchange capacities. The water saturation calculated using the new model are more representative of hydrocarbon potential of the zones of interest. In addition, cation exchange capacity calculated using this modified model and log data acquired during drilling has shown potential for diagnosis of pending bit balling of PDC bits drilled with water based mud in overpressured shale.

This research utilizes reservoir data from an oilfield in Indonesia, which is characterized by shaly sand and low salinity formation water. Both low salinity and shaliness reduce the resistivity contrast between oil and water. The aim of this research was to build a comprehensive interpretation algorithm to evaluate the shaly-sand reservoir in a low salinity formation water using limited well log data. Shaly-sand interpretation is still evolving with numerous researchers conducting investigations of the clay minerals effect on rock conductivity through theoretical and experimental approach. These investigations can be loosely divided into either Fractional Shale Volume models or the Cation Exchange Capacity (clay-type) models. This research emphasizes the Cation Exchange Capacity models. Cation Exchange Capacity (CEC) is essentially a reflection of the specific surface area of clay minerals, which causes additional conductivity in shaly-sands. The modified Silva-Bassiouni model was used to interpret shaly sand formations. This model is based on the dual water concept, however it considers that the counter-ion conductivity can be represented by an equivalent sodium chloride solution. Therefore, this method eliminates the requirement for actual CEC measurements from cores. The Shale Volume based Simandoux and Indonesia models were used for comparison. The results from the Archie clean sand model were also discussed. The model was evaluated using actual production and well test data. The modified Silva-Bassiouni model was found to yield superior estimates of cation exchange capacity and fluid saturations in the reservoirs.