bluuebunny/crossref_metadata_2025_split huggingface dataset:
Use of Rod Pump Database for Improving Artificial Lift Operations
Authors: Soza Roberto L. 
Published: December 2007

abstract
The need for data management and analysis has become crucial to the continuous improvement programs initiated in many operations. In particular, focus on improving profitability dictates that efforts onimproving production and reducing operating costs be continuously applied. To accomplish improvements an effort was undertaken to improve the quality of rod pumps used in 1500 rod pumped wells in the Andrews area. As part of this effort, it was recognized early that in order to measure and instigate improvements, an effective means of capturing and analyzing data from rod pumps pulled from wells needed to be developed. A database was developed to store rod pump run and pull data captured on a standardized pump shop repair report form. Results from this effort (along with associated improvements that will not be covered in this report) have yielded pump failure frequencies that are 40&#37; lower and pump repair job expenditures that are 60&#37; lower.
Airphoto Fracture Analysis of the Cottonwood Creek Field, Bighorn Basin, Wyoming
Authors: Prost G. L. 
Published: December 2007

Abstract
Surface mapping can be used to evaluate reservoirs where fractures influence the flow of fluids. Fracture zones mapped at the surface appear to reflect structures at depth that act as impermeable barriers to flow across the zone and as conduits for fluid flow along the zone.
Airphotos were used to evaluate a fractured carbonate reservoir at Cottonwood Creek field, Bighorn basin, Wyoming. Cottonwood Creek produces from a Stratigraphie trap in the Permian Phosphoria Formation at depths from 1538-3077 meters. Surface lineaments were interpreted on color-infrared stereo airphotos (1:58,000) and then digitized. Contour maps were generated of total surface fracture density and fracture density within various trends. These maps were compared to subsurface data to determine if they had any relationship to reservoir properties.
The principal (northwest) fracture set is unrelated to production. A map of northeast fracture density shows intense fracturing that corresponds to zones of increased total porosity-feet and high cumulative production. Enhanced recovery programs must account for these fracture zones.
Using the TQM Umbrella to Implement Business Process Reengineering
Authors: Flatt Robert N. 
Published: December 2007

Abstract
This paper analyzes the keys to successful implementation of a Total Quality Management (TQM) effort in a major oil service company over a 13-year period. A formal Quality Improvement Process began in 1982 with an initial focus upon error cause removal, employee involvement, and cross-functional corrective action teams. During the 1980's the program targeted manufacturing processes: statistical process control, just-in-time manufacturing, process capability studies, vendor partnering, and industry QA standards such as ISO 9000. Cost of quality plummeted from over 30% of sales to less than 5% during this period. In 1993 all change efforts were brought under the TQM umbrella and the focus shifted to reengineering the key business processes of the company. This paper will describe in detail how the TQM program evolved from a softer, quality awareness, people involvement process to a very results driven, radical change effort focused upon reengineering the activities, processes and structures of our businesses to reduce cycle times of all business processes, reduce costs, and improve quality and customer satisfaction. We will discuss the change imperative facing our industry and the basic concepts and principles of Business Process Reengineering and Supply Chain Cost Management. This will include a discussion of the benefits of customer/vendor alliances and partnerships and how to eliminate non-value-added activities throughout the supply chain to radically decrease cost and cycle time and improve quality. We will look specifically at two major reengineering efforts underway to dramatically improve the performance of the order fulfillment process and the goods acquisition process. We will conclude that the key to quality improvement and cost reduction in the Age of Systems of the 1990's is to simplify business processes and reduce cycle time. This paper will describe how to use the TQM umbrella to effect this change.
Deepwater Field Development Options For The Campeche Bay
Authors: Barrere Rafael Martinez 
Published: December 2007

Abstract
The Campeche Bay is located in the Gulf of Mexico Continental Slope with an average of 80 Km from the coast in front of Tabasco and Campeche states, where the most prolific reservoirs of Mexico are. Oil production in this area had represented for Pemex Exploracion y Produccion (PEP), one of the most important experiences. As a result, we had a great production structure in shallow waters with a wide experience in the usage of fixed platforms. The offshore drilling exploration activities, leaded by PEP in the recent years have allowed to find an important amount of reserves located in deeper continental slope water. For that reason we decided to make a research about the field development options for six different deepwater fields placed in water depths from 200 to 700 meters in this area. These fields are representative of various deepwater prospects that had been identified.
The objective of this study is to define the technology that is available to develop deepwater fields in this area, and to identity the scenarios that are technically and economically feasible to develop each one of those fields. The study covers all aspects of the development, throughout the life of the field. This involves a broad range of technology aspects, including drilling, production platforms, processing systems and subsea production equipment.

Introduction
The experience reached in offshore development oil fields in Mexico, began in the early 60's with the Tiburon, Atun, Bagre, Marsopa, Escualo and Arenque fields exploration and exploitation which were located in shallow waters in front of the coast of the state of Veracruz at the North of the Gulf of Mexico.
Later on, it kept on studying the Gulf of Mexico Continental Slope, giving as a result the discovery of important oil fields on the west coast of the "Peninsula de Yucatan", what today is known as 'The Campeche Bay'.
Since 1978 the exploitation of oil fields located in shallow water in water depths from 16 to 78 meters were started. Nowadays PEP has more than 100 installed platforms including several production facilities. This has permitted the establishment of the mechanisms and strategies for going into deepwater oil field developments.
PEP through the Instituto Mexicano del Petroleo (IMP) has developed the needed infrastructure to face the goals of the efficient development of its hydrocarbons reservoirs, for this reason PEP & IMP have leaded the personnel training on different specialties on a master degree basis in Universities and Institutes well known all over the world.
Also, courses and seminaries like submarine systems, floating production systems, risers and mooring systems have been organized in Mexico imparted by University professors and high education institutes, as well as different international specialists suppliers.
PEP & IMP have also participated in several joint venture studies with international companies such as:
P. 1
Importance of a Methodology to Evaluate Technology of Remotely Operated Vehicles ROV's for Deep Waters
Authors: Manrique M. S. , Niño M. S. 
Published: December 2007

Abstract
International Petroleum Industry has invaded deep water for oil and gas exploitation, Pemex has also started plans towards this objetive however, at this moment Pemex is studying deep waters technology, but in the near future will require it.
An important point is that maintenance activities in deep water can not be carried out by divers.
Therefore remotely operated vehicles are necessary. Since ROV's technology is complicated it is important to have a methodology to evaluation in order to make the best decisions in the selection and buying process.
This paper is interesting, because shows the main parameters to be consider, problems, methods and procedures for ROV's technology evaluation.
Experiences With High Energy Stimulations for Enhancing Near-Wellbore Conductivity
Authors: Snider P. M. , Hall F. R. , Whisonant R. J. 
Published: December 2007

Abstract
During the past three years, Marathon has utilized a variety of "high energy" stimulation techniques on approximately 150 wells to enhance near-wellbore conductivity. The majority of these high energy stimulation treatments have been conducted in naturally fractured limestone and sandstone intervals. A number of specialized tools to improve field operations have also been developed. The high energy stimulations utilize pressurized gas (usually nitrogen), to inject various fluid systems into the formation. These fluid systems have included clear liquids (such as acids and alcohols) and fluids containing proppants to scour and prop the created fractures. High viscosity fluids containing proppants were overbalance surged into the formation in some applications. A tubing conveyed perforating (TCP)/ proppant carrier system was developed, allowing release of proppant into the fluid stream at the instant of detonation. Typical overbalance surge pressure gradients are 1.5 – 2.0 psi/foot; however, some wells have been stimulated at pressure gradients in excess of six psi/foot.
The paper will also discuss the results of directional radioactive tracer logs that were run to determine the number of fracture planes created with these high energy stimulations. A listing of some recommended types of data acquisition and key operational recommendations are included in this paper.
A New Rock Strength Model and Its Practical Applications
Authors: Gavito Daniel Garcia 
Published: December 2007

SPE Member

Abstract
The development of a new model to predict rock strength in-situ conditions is presented in this paper. This model was obtained using experimental triaxial compression data for limestones, sandstones and shales under confining pressure conditions up to 16,000 psi. A non-linear Mohr failure envelope is considered for rock strength under triaxial pressure conditions. Results of wellbore stability analysis using several failure models are presented and comparisons are made. Rock porosity is also included in the computational procedure through correlations of this parameter with the log-derived uniaxial compressive strength of the rock. The correlations developed are also applicable for proper rock bit selection.

Introduction
Field evaluation of rock strength in-situ conditions is fundamental in today's drilling engineering. Knowledge of rock failure behavior as a function of rock type, porosity; and triaxial stresses would provide information required to properly establish wellbore stability and optimum rock bit type selection, among others. This information is critical during offshore well planning and often is a contributing factor to the successful drilling of directional, highly inclined and horizontal wells.
P. 1
First Deep Core Taken Provides the Desired Results – Mexico
Authors: Ortiz Blas , Diaz Ernesto Quiroz , Garcia Leonardo Martinez , Salinas Juan Gaspar 
Published: December 2007

Abstract
Results of record-setting deep core operation in the southern region of Mexico by PEMEX Exploration and Production showed that efficient deep core recovery-is possible in a difficult formation, even at depths exceeding 22,000 ft (6700m).
The complexity of coring limestone can involve such problems as coring jamming, which lowers recovery ratios. In addition, limestone may have fractures which can complicate core recover/ by causing jamming or restricting entrance of the core into the inner barrel.
However, in this instance, a 97% core recovery rate was obtained using a conventional 4-3/4" coring assembly with aluminum inner tubes, and a 5-7/8" × 2-3/4" natural diamond core head.
Performance data, operational details, and economic analysis concerning use of this type of coring assembly is presented. The data describes the overall success of coring performance in limestone at extreme depths.
The Mexican Natural Gas Policy: A Limited Opening with an Increase in Production
Authors: Rodriguez-Padilla V. 
Published: December 2007

Abstract
Mexico's new development and modernization strategy for the natural gas industry and market is based on two pillars: public and private investment. PEMEX, a public organism, is responsible for upstream development, whereas the private sector is in charge of downstream development. In view of macroeconomic constraints, PEMEX is currently facing difficulties in financing its activities. The government is thus discussing whether to authorize a partial opening in exploration and production activities through a special type of service contract. As for the private sector's participation in transport, storage and distribution, there are still institutional, regulatory, entreprenurial and legal questions pending that may delay or inhibit investments. PEMEX's performance is crucial for private capitals to set up and survive in the spaces that have been opened to them. Mexico's full integration to the North American natural gas market is advancing slowly since there is still a need for substantial changes in assets ownership. In any case, il is very likely Mexico will participate as a net exporter in the medium-and long-terms.
Injection of Dilute Alkaline Solutions to Improve the Recovery Factor in Oil-Wet Reservoirs
Authors: Arteaga-Cardona M. , Pineda-Muñoz A. , Islas-Juárez R. 
Published: December 2007

Abstract
An offshore Field A located at the Gulf of Mexico has shown a low recovery factor by primary production. The wettability was evaluated by the Amott method and it was found that the porous media is preferentially oil-wet.
Experimental work was undertaken in order to define the feasibility of injecting alkaline solutions to the field in order to improve the oil recovery. The purpose of these experiments was to produce surfactants in-situ to low the interfacial tension and also to react with the reservoir rock surface to modify the wettability of the porous media. The experimental work considered the injection of sea water and sodium hydroxide mixtures into cores from field A. Experimental cores were previously saturated with the field oil which has a density of 0.8928 gr/cm and an acid number of 1.2 mg KOH/gr oil. The alkaline solution was injected at the rate of 25 ml/hr in order to insure velocity displacements about one feet per day, and also reservoir conditions were achieved; displacement pressure of 1,500 psi and temperature of 100°C were kept constant.
The experimental results show that the oil recovery can be higher than 50% when the alkaline solution was injected as compared whith injection of sea water. The effect of the alkali concentration over the recovery factor is also analyzed.
Alkaline Surfactant Polymer Formulation for Saudi Arabian Carbonate Reservoirs
Authors: Al-Hashim H. S. , Obiora V. , Al-Yousef H. Y. , Fernandez F. , Nofal W. 
Published: December 2007

Abstract
This paper presents a systematic study to test the applicability of alkaline-surfactant-polymer (ASP) processes as an enhanced oil recovery method to Saudi Arabian carbonate reservoirs, with the objective of designing a cost-effective ASP slug.
To achieve this objective, several alkalis were first screened to test their compatibility with the injected sea water that has large quantities of divalent ions. Then surfactant-polymer, alkalis-surfactant, and alkalis-surfactant-polymer interactions at the reservoir temperature (90°C) were investigated. Static and dynamic adsorption of surfactant on reservoir carbonate rocks were also investigated at the same temperature. IFT measurements were also made between the slugs formulated and crude oil from the same reservoir. And finally core flooding tests were carried out using Arab-D carbonate core samples to test the effectiveness of the formulated slugs. Two surfactants were used, Triton X-102 and Ethoxylated sulfonate (Dodi-flood Β1083), and the polymer used was FLOCON 4800C.
The results of the compatibility tests showed that the ASP slug has to be prepared using a softened brine and be protected by pre- and after-flush softening brine slugs. Β1083 surfactant was found to be a promising candidate surfactant for the conditions of the Saudi Arabian carbonate reservoir. A combination of NaHCO3 and Na2CO3 was found to significantly reduce the adsorption level of Β1083 surfactant on carbonate rock at low surfactant concentrations (&lt;1% by wt.). This is very desirable for formulation of a cost-effective ASP slug. Finally, the results of core flooding tests under reservoir conditions using the formulated ASP slugs on Arab-D carbonate core samples showed a promising additional oil recovery.
Design and Optimization of Low-Cost Chemical Flooding
Authors: Wu W. , Vaskas A. , Delshad M. , Pope G. A. , Sepehrnoori K. 
Published: December 2007

Abstract
The main challenge of chemical flooding at the prevailing low oil prices is to reduce the cost. A reservoir simulator was used to systematically study a sandstone reservoir typical of an onshore, light-oil field in the United States that is a candidate for improved oil recovery using chemical flooding. These simulation results were used with an economic model to optimize the design of a chemical flood using surfactant and polymer. Project profitability was found to vary significantly at different surfactant concentrations. The best results were for the case when low concentrations of both surfactant and polymer were simultaneously injected, which is sometimes referred to as low-tension polymer flooding. Sensitivity analysis on the optimum design showed that the most important economics variables were oil price, discount rate, operating cost and chemical prices. Different polymer concentrations, permeability field realizations, and vertical to horizontal permeability ratios were also included in the sensitivity analysis. The benefits of Monte Carlo simulation as a risk assessment technique for surfactant/polymer flooding are demonstrated. Our results show that the process of designing chemical flooding projects can be improved using realistic reservoir simulations, current technologies such as horizontal wells, and an economic approach to optimization.
Foam Application in North Sea Reservoirs, I: Design and Technical Support of Field Trials
Authors: Surguchev Leonid M. , Hanssen Jan Erik 
Published: December 2007

Abstract
This paper gives results quantifying the reservoir potential and evaluating the suitability of selected foam processes for North Sea field application, extending earlier generic studies [1] to specific reservoirs and wells. Treatment of high-GOR production wells against coning and cusping, and of WAG injectors to divert injectants to less well flooded zones are reported. A fully-featured reservoir simulator with an empirical foam option is used.
For producer treatments, the application of gas-blocking foam to delay gas breakthrough is found to compete favorably with isolation techniques such as cementing and polymer-gel treatments, and offer additional benefits of selective gas shut-off, easier removal and potentially deeper treatment. History matching and evaluation of a recent foam pilot was performed and the sensitivity of the foam process to reservoir and foam parameters evaluated. Against gas coning, a treatment radius of 10 m and a mobility reduction factor of 30 may in a favorable case be sufficient to delay gas breakthrough for of several months. However, in order to be effective against gas cusping, a foam must be stronger and oil-tolerant. For injectant diversion, foam application by alternate injection of foamer followed by gas was found to offer a significant potential of improving WAG process efficiency.
If properly applied, foam can reduce gas production and increase oil production. Gas mobility reduction factor, foam persistence, volume of foamer injected, and foamer adsorption are the most critical foam parameters, while the permeability contrast and degree of communication between layers or zones are the most important reservoir parameters.
Foam Application in North sea reservoirs, II: Efficient Selection of products for Field Use
Authors: Dalland Mariann , Hanssen Jan Erik 
Published: December 2007

Abstract
This paper explains the principles of systematic product screening and qualification and evaluates the influence of the various foam, process and experimental parameters on the reliability of product selection. Because foam properties depend on the mode of application as well as on the conditions, efficient selection of a suitable foaming agent for field application can be performed only if the problem to be remedied by foam is well defined.
In order to be cost-effective, product selection should proceed in stages, conducting the required experiments in each stage only on a limited number of candidate products that have shown promising results in previous stages. Three stages may be distinguished: (i) pre-screening, (ii) screening, and (iii) qualification.
Temperature, core length, core permeability, and the use of representative crude oil and brine were found to be critical parameters in screening of foams for GOR-control application. For the cases studied, using the actual hydrocarbon gas and reservoir pressure were less critical and can be avoided if the effect of high pressure on foamer solution properties is properly accounted for. Except for cases of strongly oil-wet reservoirs, the use of reservoir material may actually harm screening due to the limitations it imposes on core length and re-use of core material possibly contaminated by previously tested products.
Reconciliation of Differences in Miscible Hydrocarbon Gas Floods Using NMR
Authors: Bowers M. C. , Purkaple J. D. , Gregory M. D. 
Published: December 2007

Abstract
Tertiary miscible core flood experiments (Lab A) were initiated to determine residual oil saturations (Sorm) for a Permian aged limestone reservoir. Cores were collected from several wells located in different areas of the reservoir and Sorm values ranged from 5.3 to 6.6%PV. The gas floods were conducted above the MMP with a 50% methane gas. In a separate project, additional floods were conducted on a different set of cores from the same reservoir (Lab B). These experiments were conducted above the MMP with a 65% methane gas and the Sorm values ranged from 10.4 to 11.9%PV. These differences in displacement efficiency will significantly impact the economics of a field scale project. The experimental procedures were compared and the differences were not significant. NMR T2 measurements were conducted on both sets of cores to examine the porous microstructures. NMR T2 relaxation curves (from which T2α, T 21, T22 and pore size distributions were derived) were compiled for each core. The T2α relaxation times associated with Lab A samples were much smaller than those associated with Lab B (i.e. Lab A cores had a much smaller mean pore size). The pore size distributions associated with Lab A cores were multimodal while those associated with Lab B cores were unimodal. Therefore, the cores had very different porous microstructures. Most importantly, Sorm was strongly correlated with T21, T22 and T2α (r =0.98, 0.94 and 0.97, respectively). As pore size increased, Sorm increased. The larger pores were apparently associated with dominate flow paths which resulted in bypassing and less efficient displacement. Secondary gas floods were also conducted and a similar relationship was found.