bluuebunny/crossref_metadata_2025_split huggingface dataset:
Production Trap Improvements Using High-Efficiency Internals
Authors: Delavan D. P. , Wilson T. T. 
Published: December 2007

Abstract
Most of the Gas-Oil Separation Plants (GOSP) in Southern Area Producing of Saudi Aramco will be producing between 40% and 75% water cuts by the turn of the century. Many GOSPs will be producing more than twice the amount of water they were originally designed for. Consequently, modifications must be made to the GOSPs so that they will have the capacity to separate and clean up these large volumes of produced water.
The most attractive option is to improve the separation efficiency of the High Pressure Production Traps (HPPT) where formation water is first removed from the wellhead fluid. These traps have historically removed very little water from the wellhead fluid. However, the following modifications have proven to significantly improve the separation efficiency of the traps: Double the height of the weir, and raise the oil level from 40% to 65% full.Install a new inlet device to minimize the formation of foam.Install coalescing and foam-breaking internals to enhance oil/water coalescing and separation and to break the foam on top of the oil layer.
Horizontal Multiphase Flow Correlations for Large Diameter Pipes and High Flow Rates
Authors: Al-Ne’aim S. A. , Aggour M. A. , Al-Yousef H. Y. 
Published: December 2007

ABSTRACT
The most widely used horizontal multiphase flow correlations have been tested against field measurements in order to determine the best correlation(s) for Saudi Arabian field conditions. A total of 450 field data points covering pipe sizes from 6 in. to 10 in., oil flow rates from 2200 to 25600 STB/D, water cut up to 60% and GOR up to 984 SCF/STB were used in this study. The standard Beggs and Brill correlation provided the best prediction considering all data combined. However, Dukler Case II correlation provided better prediction for the 6 in. pipes; and Beggs and Brill correlation was the best for the 8 in. and 10 in. pipes.
Role of Reservoir Simulation in Development and Management of Complexly - Faulted, Multiple - Reservoir Dulang Field, Offshore Malaysia : Holistic Strategies
Authors: Sonrexa Kartikay , Aziz Azly , Solomon G. J. , Bandai Malvinder , Embong Mond Khalid , Wahir Hashlm 
Published: December 2007

ABSTRACT
The Dulang field, discovered in 1981, is a major oil field located offshore Malaysia in the Malay Basin. The Dulang Unit Area constitutes the central part of this exceedingly heterogeneous field. The Unit Area consists of 19 stacked shaly sandstone reservoirs which are divided into about 90 compartments with multiple fluid contacts owing to severe faulting. Current estimates put the Original-Oil-Li-Place (OOIP) in the neighbourhood of 700 million stock tank barrels (MMSTB). Production commenced in March 1991 and the current production is more than 50,000 barrels of oil per day (BOPD). In addition to other more conventional means, reservoir simulation has been employed from the very start as a vital component of the overall strategy to develop and manage this challenging field. More than 10 modelling studies have been completed by Petronas Carigali Sdn. Bhd. (Carigali) at various times during the short life of this field thus far. To add to that, Esso Production Malaysia Inc. (EPMI) has simultaneously conducted a number of independent studies. These studies have dealt with undersaturated compartments as well as those with small and large gas caps. They have paved the way for improved reservoir characterization, optimum development planning and prudent production practices. This paper discusses the modelling approaches and highlights the crucial role these studies have played on an ongoing basis in the development and management of the complexly - faulted, multi-reservoir Dulang Unit Area.
Improving the Performance of MARS Reservoir Simulator on Cray-2 Supercomputer
Authors: Li K. G. , Dogru A. H. , McDonald A. E. , Merchant A. R. , Al-Mulhem A. A. , Al-Ruwaili S. B. , Sobh N. A. , Al-Sunaidi H. A. 
Published: December 2007

ABSTRACT
The computational efficiency of a reservoir simulator–MARS–that is heavily used in Saudi Aramco, was significantly enhanced by improving the vectorization, parallelization and a key algorithm of the simulator. In particular, a state-of-the-art parallel linear equation solver was developed and implemented in the simulator. This new solver ran three to five times faster than the existing solvers. With the new solver and the other improvements in the simulator, the optimized code ran 1.3 to 1.8 times faster than the original code on a single processor and more than four times faster on four processors of Cray-2 supercomputer for typical Saudi Aramco reservoir models. This translates into great savings for the company since it, in effect, creates additional computational resources at no additional cost and improves the reservoir engineer’s productivity by shortening the job turnaround time.
Platform Evaluation Of An Offshore Field
Authors: Huang K. L. , Saleri N. G. , Al-Khowaiter A. O. 
Published: December 2007

Abstract
A numerical study of an offshore field was performed to evaluate the relative performance of horizontal versus conventional wells, and various well completion/ placement/production scenarios for a six-well platform.
The results presented in this paper are found to be counterintuitive. While horizontal/high slant wells showed delayed gas and/or water breakthroughs, the overall platform performance remained largely insensitive to well configuration (horizontal versus conventional). Well placement, completion interval, and production strategy after breakthrough were identified to be the critical parameters in determining the performance of the platform. The study results favour conventional completions for this particular six-well platform.
New Completion Design for Step Horizontal Well
Authors: Kikuchi Shuichi , Al Mansoori Bader 
Published: December 2007

ABSTRACT
In ADMA-OPCO, step-horizontal drilling technology, is often adopted i.e two horizontal sections in different sub layers inter-bedded by an impermeable barrier. For this kind of horizontal well, the following requirements in the completion phase as well as during the life of the well are to be taken into account -:a) Effective isolation between different sub layers to cope with future water breakthrough, b) Selective stimulation, c) Leaving several options for remedial workover operations, d) The capability to production log. With view of these, a specific completion for the step-horizontal well namely "dual External Casing Packers (ECPs) plus port collar system" has been successfully developed. This paper presents the design process and discusses equipment selection, running procedures and precautions required for this unique completion.
Oil Base Mud in High Pressure, High Temperature Wells
Authors: Soliman A. Abou 
Published: December 2007

ABSTRACT
ADCO’s experience while drilling the sixth deep Khuff well with water base mud to total depth of 21682 ft and a bottom hole static temperature of 465°F has highlighted mud related problems. The mud has shown gelation, barite sagging, sensitivity to formation water influx and possible instability at densities higher than 122 pcf. These problems were considered in the selection criteria of the drilling fluid for the seventh deep Khuff well which required a drilling fluid density of 110–140 pcf with stable HTHP fluid loss at temperature up to 465°F, capable to tolerate influx of Co2, H2S, and high salinity formation water.
Studies on various oil & water base muds were performed in various laboratories including ADCO’s, the Shareholders’ and the mud companies’. The development of stable water base mud was not possible. Oil base mud formulation was developed and has been used.
The well has reached its total depth at 20085 ft & a bottom hole temperature of 440°F after facing operational challenges requiring mud weight of 155 pcf to control the well and during which, the OBM choice proved to be a success.
GOS Hook Type Wells, Directional Planning, Techniques Applied and Problems Encountered
Authors: A/Azim Mostafa , Fahmy H. , Salem A. , Mansour Sayed 
Published: December 2007

ABSTRACT
This paper addresses the various aspects of hook type wells introduced and drilled within GUPCO operations during the last two years. The first well of this category was October-G10, drilled in October 1992 from October "G" platform to a target point in the Nubia formation. Several wells of the same type have been drilled through 1993 and 1994. This group includes October-Hl, Ramadan 3–57, July 62–69 and SB 374-3. Drilling hook type well profiles has resulted in increased production and more reserve recovery. The driving force behind using this profile was the reservoir requirements where it was required to hit a target within few meters at a certain angle and direction.
Torque and drag models have been used to optimize well path planning, resulting in lower torque and drag values. Daily post appraisal of the drilling operations to monitor hole cleaning effectiveness. Combination of advanced steerable systems and PDC bits enabled GUPCO to drill these wells cost effectively.
Drilling Operations in the Mediterranean Concessions: Challenges for Drilling Engineers and Rig Personnel
Authors: Hussein Nasr K. , Alsayed Nabih A. , Abu Seif Mohamed A. , Shalaby Shouhdy A. 
Published: December 2007

ABSTRACT
Exploration offshore Mediterranean in Egypt is getting more and more important due to gas reserve discovered by ΓEOC in Port Fouad, Baltim and Temsah concessions. This paper will discuss some of the challenges required to drill safely and economically through the overpressurized sensitive shales of Nile Delta basin. It also summarises the problems encountered while drilling the very high pressure wells in Port Fouad and Temsah concessions, such as: hole instability, mud problems, water and gas kick, overpressure detection, lost of circulation, casing setting depth and related design, running and cementing operations, environmental pollution, safety and logistic problems.
Experience gained from the past and undergoing drilling operations in offshore Mediterranean is included in this paper and it could be a support for future exploration and development in the area.
Integrated Reservoir Modelling of a Major Arabian Carbonate Reservoir
Authors: Benkendorfer J. P. , Deutsch C. V. , LaCroix P. D. , Landis L. H. , Al-Askar Y. A. , Al-AbdulKarim A. A. , Cole J. 
Published: December 2007

ABSTRACT
This paper presents the results of an integrated reservoir management study of a large carbonate reservoir. Geostatistical and scale averaging tools were used to develop detailed geologic models and a simulation window model. The geostatistical simulation techniques generated realistic models of lithology, porosity, and permeability. The public-domain GSLIB software, with some custom programs for data manipulation and interactive variogram modeling, allowed for the timely and efficient construction of a multi-million cell geological model. A two-step approach to permeability modeling was successful; it allowed the straightforward integration of core and well test data and provided improved geologic models for use in history matching in flow simulations. Because of the large number of cells in the geologic model, the porosity and permeability models were scaled up for use in the simulation model. A calibrated power-law average approach to scale-up was found to work well.
The geostatistical tools used in this study are applicable to both siliciclastic and carbonate reservoirs. The two-step approach to permeability prediction is applicable whenever a significant difference exists between core-based permeability measurements and production-scale permeability. The authors suggest that such an integrated approach to reservoir management is widely applicable and yields good results.
This paper presents an overview of the methodology and techniques used to develop the geologic and simulation models for the area being studied.
Utilization of Horizontal Drainholes in Developing Multilayered Reservoir
Authors: Siddiqui Tariq K. , Al Khatib Hassan M. , Sultan A. Junaid 
Published: December 2007

ABSTRACT
Drilling deviated wells in the Upper Zakum field did not allow to develop this field to its full potential. It is an offshore field, only a limited number of platforms are available. Therefore, it may become uneconomical to drill a large number of deviated wells for the full development of the reservoirs. Application of horizontal wells in this field helped in redeveloping the reservoirs.
Data were integrated from different petroleum engineering disciplines and analyzed to identify problems in the reservoirs. Horizontal wells played a vital role to resolve various problems faced in different parts of these heterogeneous reservoirs.
This paper reviews the field development strategy which was further refined with time as more horizontal wells were drilled in this field. Performance of horizontal wells have been compared and evaluated with the deviated wells. A brief discussion on drilling, completion, and stimulation procedures used for horizontal wells has also been included.
This study contributed to some extent in resolving reservoir problems ranging from enhancement of productivity index, development of reservoir flanks, and recovering un-swept oil from water flooded layers with the applications of horizontal wells
Innovative Use of Horizontal Wells in Mature Fields Boosts Production/Reserves
Authors: Baack William , Latif Mahmoud 
Published: December 2007

ABSTRACT
Many Gulf of Suez fields operated by the Gulf of Suez Petroleum Co. (GUPCO) were discovered in the early 1970’s and are in the mature stages of depletion, requiring application of advanced technology and multi-discipline focused teams to identify bypassed oil. These fields are structurally and geologically complex, with bypassed oil potentially underlying faults or gas caps in highly stratified reservoirs of varying rock properties. Significant vertical well development often precludes conventional application of horizontal well technology. Non-conventional application of horizontal drilling in the late stages of depletion has aided development of resources where vertical wells are not viable.
Several field examples are discussed and illustrate the innovative use of horizontal wells to boost production and reserves. Horizontal wells are used to drill under faults to intersect multiple layers of thick reservoirs and to explore areal extension of reservoirs. Horizontal wells are also used to intersect appropriate reservoir layers in gravity drainage and gas cap reservoirs to improve rate and recovery. In each of these cases, multi-discipline teams identified the development potential, planned wells to meet objectives, and used real time data to ensure objectives were met.
The concepts used in the these field cases are being applied to other GUPCO fields as multi-discipline teams are assigned to study them. Success in these applications of horizontal wells along with conventional application of horizontal wells is helping GUPCO to boost production and increase reserves from mature fields.
Wettability Evaluation of a Carbonate Reservoir Rock from Core to Pore Level
Authors: Al-Yousef H. Y. , Lichaa P. M. , Al-Kaabi A. U. , Alpustun H. 
Published: December 2007

ABSTRACT
Wettability evaluation was performed during stages of as received, cleaned, and restored states on core samples from a Saudi Arabian carbonate reservoir. The wettability behavior from the chemistry of brine-oil-carbonate rock interaction was found to be neutral to slightly oil-wet. The pore-size distribution obtained from mercury injection data indicated that about 15–20 percent of the pore volume is not accessible to asphaltene particles in the crude oil. Therefore a mixed-wettability state can exist. These results were confirmed by the evaluation of the wettability of the cores using USBM and Amott techniques.
The wettability at the pore level was studied using Cryo-Scanning Electron Microscopy. Rock samples were examined at irreducible water and residual oil saturations during cleaned and restored states. At irreducible water saturation, both oil and brine were present in the intergranular macroporosity and intragranular macropores and micropores. At residual oil saturation, oil was found in the form of isolated globules in the cleaned case. After aging, the oil is more loosely distributed in the porosity and generally contacts the pore walls. This indicates an evolution toward oil wetness with aging. These results are in agreement with the changes of wettability indices obtained using USBM technique.
Resistivity Index and Capillary Pressure Hysteresis for Rock Samples of Different Wettability Characteristics
Authors: Elashahab B. M. , Jing X. D. , Archer J. S. 
Published: December 2007

ABSTRACT
This paper presents the results of an experimental investigation into the effects of hysteresis (saturation history) on resistivity index and capillary pressure characteristics for some sandstone rocks of different wetting character. The drainage and imbibition resistivity index and capillary pressure measurements were carried out at equilibrium conditions using oil and brine with semi-permeable membranes. The displacing-cycle dependent hysteresis was also investigated experimentally. The resistivity profiles along the core length obtained from six potential electrodes enabled the assessment of equilibrium conditions, core and saturation heterogeneity and the end effects.
All test samples ( except for an oil-wet sample) were initially saturated with brine and placed in a multi-sample coreholder with a water-wet membrane at one end of the sample and an oil-wet membrane at the other end. A mineral oil was injected through the oil-wet membrane in incremental capillary pressure steps while a fixed back pressure in the water phase was maintained. At the end of the oil-displacing-water cycle, brine was then injected back through the water-wet membrane by decreasing the oil-phase pressure in steps until reaching the maximum entry pressure of the oil-wet membrane. To study the displacement-cycle dependent hysteresis the second desaturation cycle was performed on some samples from the oil saturation remaining after a water-flood at the end of primary saturation.
Our results indicate that both the displacing-phase and displacing-cycle dependent hysteresis should be taken into consideration for relevant resistivity index and capillary pressure curves. The hysteresis effects were also found to depend on the wettability of the rock samples. A parametric study was presented to highlight quantitatively the petrophysical effects.
Estimation of Condensate Dropout Effects on Well Productivity as Skin Change with Multiplicative Interactions Among Skin Components
Authors: Hwang M. K. , Odeh A. S. 
Published: December 2007

ABSTRACT
This work deals with well productivity reduction due to altered formation permeability and other flow restrictions around a vertical wellbore. This near-wellbore formation change can be caused by liquid dropout in a gas condensate reservoir, for example. The corresponding reduction in well productivity can be quantified as an increase in the total skin (St). According to the conventional method, the total skin is given by a sum of individual components: St = Sm + Sp + Sd + Sa, where Sm represents flow restrictions from mechanical damage, Sp from partial completion, Sd from non-Darcy flow effect, and Sa from permeability reduction due to liquid dropout. The key finding of this work is that the total skin with condensate dropout can be much bigger than (Sm+Sp+Sd+Sa) due to nonlinear multiplicative fluid-dynamic interactions among skin components. These interactions have not been fully recognized and accounted for in literature. Two correct methods are presented for the total skin calculation in a multi-layered formation: direct simulation and heuristic analytical approximation. The analytical approximation equation is simple, but very accurate in most cases under the pseudo-steady state condition, when compared to the direct simulation method.
The new equation developed here has significant implications in various engineering analyses. The conventional method can grossly overestimate well deliverability, if the total skin value is computed from individual components. Conversely, when an individual component (such as Sm) is back-calculated from the total skin obtained from pressure transient analysis, the conventional method can grossly overestimate Sm. Also, this new equation can be used to predict simulation impacts of different wellbore description and of adjustments made in permeability distributions and skin components during history matching.
Transient Pressure Data Interpretation of Horizontal Wells in a Multilayered Reservoir
Authors: FURUYA M. , TAKAHASHI S. 
Published: December 2007

ABSTRACT
This paper presents the results and the use of the interpretation of pressure transient data of a horizontal well in a multilayered heterogeneous reservoir. The well was drilled as a pilot horizontal oil producer with objectives to understand both the reservoir characteristics and the mechanism of water breakthrough in nearby producers due to pattern water injection.
Interpretation was first conducted using well test analysis packages, then the analytical results were verified by numerical simulation models.
This paper addresses the test interpretation findings and sets planning guidelines for pressure transient tests of horizontal wells.
Planning and Execution of a Record-Extended Reach Well in Japan
Authors: Benesch J. M. , Camacho A. G. , Matsuzawa S. , Dawson C. R. 
Published: December 2007

ABSTRACT
The Johban Oki-2 well was drilled to a total depth of 4,984 m and reach of 3,881 m from the Iwaki platform located offshore Japan. Drilled and completed in 57 days during 1994, this well is believed to be the longest reach well in Asia.
Optimization of the Numerical Simulation in a Giant Oil Field by Upscaling of Relative Permeability Curves
Authors: Giliberti Stefano , Erba Mario , Rampoldi Maurizio , Said Ali 
Published: December 2007

ABSTRACT
This paper presents the methodology applied to optimise the dynamic simulation of the giant Bu Attifel oil field (Libya) producing for 21 years under water injection.
When building the full field model of a giant field it is fundamental to limit the number of cells and CPU times without jeopardising the structural and sedimentological complexity of the reservoir. This will allow a correct simulation of future development phases, such as improvement in water injection (production-injection scheme optimisation, infill wells) and EOR processes (gas injection).
The first step of the study was the construction of two-dimensional cross sections based on the geological and dynamical data of the most representative wells. Then different oil displacement processes (water injection and gas injection) were simulated, mainly varying vertical communication and anisotropy of layers. Groups of relative permeability pseudo functions, consistent with the different geological configurations, were used in the full field model to simplify and optimise the history match phase.