bluuebunny/crossref_metadata_2025_split huggingface dataset:
Asphaltene Deposition and Chemical Control in CO2 Floods
Authors: Yin Y. R. , Yen A. T. 
Published: December 2007

Abstract
CO2 miscible gas flooding is a popular method of improved oil recovery. Asphaltene deposition in many of these systems is a costly operational problem associated with the utilization of this method of recovery. A CO2 flood in West Texas was experiencing major problems with asphaltene deposition related ESP failures and tubing plugging.
Operational procedures, field experience and a successful chemical program have greatly reduced the cost of these problems over the last 3 years. A new inhibitor for continuous capillary injection has been recently developed and used in successful field trials. To evaluate the field performance of this new asphaltene inhibitor, a wellhead side stream filter loop was constructed to monitor asphaltene precipitation/deposition. The objective was to measure and compare the time needed to plug a given size filter by untreated and chemical treated produced fluids. Pressure data at the filter loop and wellhead was also recorded to monitor the effectiveness of the treatments.
The field trial results proved the use of a filter-plugging side stream was an effective way of assessing asphaltene inhibitor performance. Based on the filter plugging and wellhead pressure data, it was concluded that asphaltene precipitation/deposition occured if the produced fluid was not chemically treated. The currently used product with successful prior field results was able to reduce asphaltene deposition and doubled the filter plugging time. The new asphaltene inhibitor was shown to be more effective for stabilizing the asphaltenes in the CO2 flooded produced fluids. The new inhibitor extended the time needed to plug a filter by more than four times as compared to untreated fluids.
Case history information, laboratory tests results, side stream configuration, field test procedure and field test results are presented.
Waterflood Redevelopment of the Marmul Haima-West Reservoir, Oman
Authors: Cook R. C. H. , van den Broek L. H. W. M. , Koelman J. M. V. A. 
Published: December 2007

Abstract
The Marmul Haima-West reservoir is being redeveloped from depletion recovery with vertical producers to a line drive waterflood with horizontal injectors and producers. The presence of mica/pyrite rich shale layers within the reservoir sands results in a suppressed log resistivity response. Recognition of this effect led to a 225% increase in field oil initially in place (OIIP) to 1,270 MMstb of 23° API crude. Full-field waterflooding is forecast to increase the ultimate recovery factor from 6% to 24% of OIIP resulting in incremental reserves of 233 MMstb. The pattern waterflood horizontal producers will be completed without downhole sand exclusion. By utilizing horizontal wells and coproduction of sand, well productivity has been increased by a factor of eleven.
IOR Evaluation and Applicability Screening Using Artificial Neural Networks
Authors: Surguchev Leonid , Li Lun 
Published: December 2007

Abstract
The oil industry relies heavily on predictions of the recovery processes in order to make sound operational decisions for reservoir exploitation. For planning of IOR applications, one would like to predict the performance of several competing strategies before making a decision. The main tool for performing such prediction is the reservoir simulator. The reservoir simulators (1) require extensive information about the reservoir that may not be available or can be unreliable in the initial evaluation stage, and (2) are quite computer intensive programs.
Very often decisions on recovery strategies should be taken in an early stage of field development planning. A reliable first order screening evaluation tool enables the makimg of critical decisions on potential recovery strategies with the limited reservoir information. A multicriterion model based, on the method of Artificial Neural Networks (ANN) and interval theory, has been applied to the assessment and screening of EOR/IOR processes, such as water and gas shut off methods. An assessment relies on the existing industry experience and field practice at different reservoir conditions. It is based on applicable ranges for key reservoir parameters (permeability, porosity, depth, fluid properties, heterogeneity, rock type, salinity, etc.). Historic data are used for ANN training by Back Propagation (BP) and Scaled Conjugate Gradient (SCG) algorithms. The ANN model permits an integration of different types of data, eliminates arbitrary approach in making decisions, and provides fast computation and accuracy. The developed ANN model is capable of assessing the efficiency of a large number of EOR/IOR and well shut-off methods even when key reservoir parameters are defective or noisy.
Compositional and Phase Behavior Experimental and Theoretical Work on Hydrocarbon Mixtures and Several Solvents (Carbon Dioxide, Nitrogen, and Flue Gases)
Authors: de Ribeiro Augusto Lino Ulysses 
Published: December 2007

Abstract
Research on compositional and phase behavior of hydrocarbon mixtures and solvents is of great importance to the improvement of oil recovery. Series of experiments consisting of constant composition expansion, multiple-contact processes and constant volume depletion were performed employing three multicomponent hydrocarbon mixtures and four solvents (carbon dioxide, nitrogen and two flue gases). The results permitted to determine the hydrocarbon recovery efficiency for each solvent as a miscible-immiscible-gas process. In the modeling of IOR projects based on miscible-immiscible-gas processes, complex compositional models are employed. These models are based on equation of state (EOS) calculations. As part of the research work performed, an improved cubic EOS model was developed which can be used for more accurate compositional and phase equilibrium calculations than the previous models. The new model is based on a modification of the function used for calculating the cross-parameters aij and bij of the EOS mixing rules. The new model can be used for various applications, including the improvement of the currently used compositional numerical reservoir simulators. The application of the knowledge produced from the experimental and theoretical work presented permits to answer a series of questions such as "Can a flue gas or a mixture of carbon dioxide be used instead of pure carbon dioxide in a particular miscible project?"
Studies of a Relative Permeability Modifier Treatment Performed Using Multitap Flow Cells
Authors: Dalrymple E. D. , Eoff L. , Reddy B. R. , Botermans C. W. , Brown D. , Brown S. 
Published: December 2007

Abstract
Relative permeability modifier (RPM) treatments are designed to (1) reduce the quantity of water produced from the formation or (2) reduce the water-oil ratio (WOR) of the produced fluids without significantly damaging the hydrocarbon-production potential of the zone. Ideally, the RPM chemical should alter the flow properties of the fluids traveling through pore spaces rather than block the pore spaces. However, the laboratory methods and procedures typically used for evaluating RPM's are actually modified versions of those used for evaluating full blocking agents.
The RPM effect is measured by determining the changes in the drag forces through the pore throats to specific fluids (water, oil, and gas) rather than simply blocking the pore throats to the flow of all fluids. Therefore, a different approach was used in the physical-model flow-testing procedure. Flow studies were performed to measure the effectiveness of RPM treatments at distinct points throughout the core as the fluids traveled through rock test cores. The following water- and oil-saturation levels were examined:
100% water water with residual oil oil with residual water
Permeability was varied between −2000 md and 20 md. Placement procedures were also varied. Some tests included single cores; others included treatments of two cores arranged to represent parallel flow stringers within a formation. The two cores, arranged in parallel, were saturated using a method to best represent the type of layer desired; one core represented a water layer, and the other represented an oil layer. A bullhead technique was used for placing the RPM chemical. Both carbonate and sandstone lithologies were examined.
This paper compares the results of conventional testing methods to those of testing methods used for the multipressure tap flow procedure. The results illustrate the importance of examining fluid flow throughout the length of the formation rock sample instead of simply evaluating a single measurement across the entire core. By using a multipressure tap flow cell to determine the effect of permeability changes throughout the length of the core, it was possible to help prevent the observed data from being skewed by "end" effects. This paper also describes laboratory procedures and schematics of the physical laboratory-scale model. Operators can use this information to (1) determine whether an RPM treatment can be applied to water-production problems resulting from sources such as coning and high-permeability streaks, (2) assess the potential damage to hydrocarbon production caused by such treatments, and (3) calculate the treatment volumes necessary for addressing different types of water-production problems.
Potential for Horizontal Well Technology in the U.S.
Authors: Biglarbigi Khosrow , Mohan Hitesh , Ray Robert M. , Meehan D. Nathan 
Published: December 2007

Abstract
The application of horizontal wells has increased tremendously with significant and positive results in the United States over the past decade. The pace of horizontal drilling (for oil) has remained high at about 600 to 1000 wells per year since 1990. Most of these wells have been drilled in three (3) formations: the Austin Chalk (79%) in Texas, the Bakken Shale in North Dakota (5%), and the Niobrara (2%) in Colorado and Wyoming. Wells in other formations constitute about 14%. The Department of Energy National Petroleum Technology Office (DOE/NPTO), working closely with industry, has developed a unique analytical system (including models and database) to asses the potential for the wider application of technology to the balance of the remaining domestic oil resources across a variety of formations. The findings of the DOE effort are the primary scope of this paper.
Experimental Hydraulic Fracture Propagation in a Multi-Fractured Medium
Authors: Beugelsdijk L. J. L. , de Pater C. J. , Sato K. 
Published: December 2007

Abstract
In scaled laboratory experiments, we investigated the interaction of a propagating hydraulic fracture with natural discontinuities. We observed the hydraulic fracture geometry as a function of horizontal stress difference, stress regime, flow rate and discontinuity pattern. We observed the smallest amount of interaction for high flowrates. When the horizontal stress difference was increased, the fracture was smoother. However, when we represented the tectonic stress ratio's, with a lower vertical stress compared with the maximum horizontal stress, we observed a higher fracture tortuosity.
Development of Multiphase Flowmeter Without Radioactive Source
Authors: Fueki M. , Urabe S. , Yamazaki D. , Yamashita M. 
Published: December 2007

Abstract
Development of a multiphase flow metering system, that measures unseparated oil, gas and water flow rates, is one of the key technologies to improve subsea production. The application of a multiphase metering system benefits subsea oil and gas production. Japan National Oil Corporation (JNOC), Yokogawa Electric Corporation, NKK Corporation, Japan Petroleum Exploration Corporation Ltd. and Teikoku Oil Company Ltd. launched a joint project in April 1995 to develop a multiphase flowmeter.
We are developing a multiphase flowmeter, that is safe for both the personnel and the environment, because there is no use of a radioactive source. And it has no moving parts in order to meet the requirement of easy maintenance. The flowmeter consists of two impedance component fraction sensors, venturi-meter and cross-correlation technique with two component fraction sensors.
The performance of this meter was evaluated in both 2[inch] and 4[inch] multiphase flow test loop using lubricant oil or kerosine, tap water, and air or nitrogen as test fluids. Three-phase flow tests were carried out in mixing velocity 3[m/s] with 0.5[MPa] line pressure. The tests for two-phase flow with 0.5[MPa] and 2[MPa] were carried out. Most of the test results show that the total multiphase flow rate error (TM error : specified uncertainty of one phase / multiphase flow rate) of kerosine and water phase are within +/-10[%]. However nitrogen flow rate was under estimated.
Simulating Aerated Drilling
Authors: Sharma Y. , Kamp A. , Yonezawa T. , Rivero L. M. , Kobayashi A. , González J. 
Published: December 2007

Abstract
A steady-state model is presented to study the simultaneous flow of three phase gas-liquid-solid mixtures in conduits. The liquid phase can be comprised of a mixture of Newtonian (e.g. liquid hydrocarbon, water) and non-Newtonian (e.g. drilling mud) fluids. Gas can exist in a free state as well as dissolved in the liquid phase. The model accounts for possible injection of separate streams of gas, liquid hydrocarbon, and water into the conduit. The solid phase is assumed to be fully suspended in the multiphase flow mixture.
Component mass balances are written for the liquid hydrocarbon, water, non-Newtonian liquid, transported gas, injected gas, and solid. The set of balance laws is completed with a mixture momentum equation. Closure of the system of equations is effected by two drift flux equations, relations for fluid properties, mixtures, friction factor, wall shear stress, and component mass fractions. Solubility of gas is described by a black oil behaviour.
An iterative finite difference approximation scheme is used to solve the system of equations. The conduit is divided into segments. The set of equations is solved simultaneously over each segment, and progressively over the conduit.
The model is used to simulate an ubderbalanced drilling operation. The predicted bottom hole pressure compares well with that obtained fromPWD data. The results represent preliminary studies with the model and simulator and serves to identify additional work on a continuing collaborative effort to develop technology related to underbalanced drilling.
Mltbs Project Challenging for Reservoir Benefits
Authors: Kikuchi Shuichi , Fada'q Abdulla S. 
Published: December 2007

Abstract
Multi-lateral completion technology is evolving rapidly and continuing to mature in order to provide new methods for reservoir management and increase production potential.
ZADCO (Zakum Development Company) in conjunction with ADNOC (Abu Dhabi National Oil Company) / JODCO (Japan Oil Development Company) / JNOC-TRC (Japan National Oil Coraporation -Technology Research Center) / ADMA-OPCO (Abu Dhabi Marine Operating Company) and SSDS (Sperry-Sun Drilling Services) has successfully completed MLTBS Phase-1 (Multi-Lateral Tie Back System) utilizing an existing well, a level 5 TAML (Technology Assessment Multi-Laterals) completion and level 4 TAML hydraulic isolation.
MLT(Multi-Lateral Technology) application for the existing well was the first achievement in the world. In addition, several new technologies such as running and full cementing 7" liner in 8-1/2" lateral, recording cement evaluation logs over the cased lateral using TLCS (Tough Logging Condition System), and perforating the cased lateral with one run using TCP (Tubing Conveyed Perforator) were firstly implemented in UAE.
Three years of R&D, integrated planning, and testing were required by MLTBS project team before attempting the extremely aggressive trial.
The ultimate success of the Phase-1 trial on Well-A will encourage introducing MLTBS into Upper Zakum field to -:
Re-establish dry oil production by locating the horizontal section in an optimum layer of upper reservoir. Allow access to upper cased lateral and lower barefoot lateral on demand through the newly designed dual completion. Achieve effective stimulation increasing production capacity of both upper cased lateral and lower barefoot lateral. Leave future options for reservoir monitoring and extending the well life by drilling a secondary lateral or applying selective water shut-off in the upper cased lateral.
MLTBS will provide planning flexibility to exploit reservoirs to their maximum potential, allowing ZADCO to create new development strategies.
Reservoir Modelling Assists Operations to Optimize Field Development: Serang Field, East Kalimantan
Authors: Vo D. T. , Sukerim _ , Ivanowicz Mark , Syahrani _ , Bouclin Denis , Clark Tom , Stites Jim , Partono Yoseph 
Published: December 2007

Abstract
Located offshore East Kalimantan, Indonesia, the Serang Field consists of complex multi-layered reservoirs with strong aquifers and large gas caps. The dynamic change of fluid distribution and saturation in these reservoirs due to production poses a unique challenge for managing and developing the field. Issues important for reservoir management involve locating and defining fluid contacts, optimizing well placement and their timing, selecting proper completion techniques, and identifying potential workover candidates to capture additional recovery.
This paper presents a field case study describing the use of reservoir modeling to assist operations to manage and optimize the Serang field development. The model constructed helps explain the reservoir fluid flow behavior, its production characteristics, and is subsequently used to plan for the field development strategy. Based on modeling results, value-based recommendations are made with focus on selecting optimal infill locations, completion techniques, wellbore placement and timing, identifying workover candidates and recompletion potential, and forecasting flow rates and reserves. Results from current development drilling program with emphasis on using horizontal wells for improving recovery under gas-cap gas and strong aquifer support are presented. Specific strategy used in planning and completing these horizontal wells is also discussed.
The paper demonstrates that reservoir modeling as an integral part of the asset team, plays an important role for technical decision, bridges communication between cross-disciplined team members and becomes a useful forecast tool to help manage the asset and increase its value.
A New Project Evaluation Tool –Risked Rate of Return
Authors: Inoma Akitoshi 
Published: December 2007

Abstract
Hydrocarbon exploration has world-widely become mature and only remote areas are remaining as new frontiers. This brings forth increase of exploration costs. Under these situation, risk analyses or feasibility studies for new projects, especially for exploration projects, have increased their importance. "ROR" has been popularly used for a long time to judge the profitability of projects. But it assumes a discovery of a certain volume of oil or gas accumulation and does not mention the probability of the success. Another important factor to be considered in selection of projects is a probability of the success or a probability of discovery with more than minimum economical size. Recently, the probability is given in a form of probability distribution. A probability distribution of expected reserves and a feasibility criterion such as ROR are still separately used in many companies.
Here I intend to introduce the concept and the calculation procedure of a new feasibility criterion "Risked ROR". This combines the success probability and ROR. By using this concept, plural projects are comparable with each other based on single criterion instead of using two criteria. For this purpose, companies only need to prescribe a certain yardstick value of risked ROR as a company policy.
Development of Pressure Regulating & Heating System for High-Pressure Gas Pipelines
Authors: Mori Takao , Noguchi Akihiko , Nasu Yuuki , Imai Hideki 
Published: December 2007

Abstract
Gas pipelines in Japan tend to be operated in higher pressure than before because of the increase of gas demand.Especially in the latest thermal power plants, a large amount of fuel gas is consumed from high-pressure pipelines for advanced turbine generators or for huge steam boiler systems. In such a power plants pressure and temperature of supply gas should be controlled within the allowed narrow range even if gas demand changes suddenly. We have developed the advanced control system to maintain pressure and temperature of supply gas sent out from high-pressure pipeline via the pressure regulating and heating facility. It has been installed in some large thermal power plants in Japan. This paper describes engineering experiences of this regulating and heating system, and introduces the dynamic simulator that has been developed to predict the vibration in varied situations.
Pressure Derivative Matching Method for Two Phase Fluid Flow in Heterogeneous Reservoir
Authors: Masumoto Kiyoshi 
Published: December 2007

Abstract
Automatic history matching method for simultaneous matching at pressure and its derivatives for two phase fluid flow in heterogeneous reservoir was developed. Adjoint method was used for calculating gradients of new objective function which consists of two parts; one is the original term and the other is the sum of differences between calculated pressure change rate and observed change rate. A set of two phase fluid flow equations which includes capillary pressure are used for calculating pressures and its change rate in the objective function. Quasi-Newton method (Self Scaling Variable Metric Method) was used as optimization algorithm. The one dimensional heterogeneous permeability distribution was estimated with the proposed method for a simple numerical model case. With this method, transient flow behavior in heterogeneous reservoir with multiple phase condition was applied for automatic history matching without too much computing time.
Automatic Continuous-Measuring System of Interfacial Tension by Spinning Drop Technique
Authors: Yamazaki T. , Okabe H. , Akita Y. , Aso K. 
Published: December 2007

Abstract
Surfactant/polymer and alkaline/surfactant/polymer (ASP) floodings have been mostly used in worldwide oil fields as an effective enhanced-oil-recovery method. The principles of these chemical floodings are to reduce the interfacial tension between oil and flooding solution of alkaline/surfactant.
The spinning drop technique has been used to evaluate the interfacial tension between oil and the solution by measuring the shape of the oil drop in the flooding solution contained in a capillary tube. Until now, the shape of the drop has been measured by micrometer of a microscope. This method, however, often brings on human errors and a great time-loss. In order to eliminate these defects, an automatic measuring system has been newly developed by combining a video-image analysis, an automatic recording system, and a computer for calculation of the interfacial tension under the spinning drop technique. The features of this system are as follows:
It enables to measure and record the interfacial tension automatically for a long time. It enables to change the measuring time and the recording interval very easily by programming. It reduces human errors and contributes to laborsaving.