bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Interactive Web Site Provides Oil Field Emergency Response Resources
Authors: Veil J. A. , LePoire D. J. , Richmond P. D. , Roloff K. G. , Gasper J. R. , Johnson R. L. 
Published: January 2008

Abstract
Emergency responders historically have not been provided with specialized training or assistance for spills and fires at oil field sites. This situation has lead to potential safety hazards for responders, and, in some cases, inappropriate response efforts have been made. Planning for emergency oil field incidents has been hampered by the sheer number of individual oil field sites. The Ohio Department of Natural Resources, in conjunction with the Ohio oil and gas industry, conceived a multimedia program to provide training and resources to emergency responders for dealing with oil field emergencies and to provide better resources to response planners. Argonne National Laboratory (Argonne), through funding from the U.S. Department of Energy's National Petroleum Technology Office, developed an innovative interactive web site that provides online information to emergency responders and response planners.
The web site consists of three modules that allow responders and planners to rapidly obtain information about well sites. The "Find a Well" module utilizes multiple graphical information system (GIS) layers and the Ohio Risk-Based Data Management System (RBDMS) database to allow users to identify well owner/operators, and well proximity to roads, streams, schools, and other important features. Using Argonne's Maps and Data (MaD) Java applet, users are able to download and interact with detailed maps by using standard web browsers. The web site also includes "Reporting" and "Resources" modules to provide information to users on the necessary reporting requirements following a spill or fire, as well as access to many other government and private resources for additional information.
The Ohio web site is considered to be a pilot project and can be modified for use in other states or for other purposes, such as Safe Drinking Water Act source water protection programs, for example. Depending on a user's needs, additional GIS data layers can be added to the system to provide more information.
Tapping Intellectual Capital for Service Improvement
Authors: Beatty Jonathan E. , Conners Sandra L. , Day Peter R. , Martin Charles A. , Regrain Emmanuelle A. 
Published: January 2008

AbstractIncreasingly, oil and gas companies look to service providers to deliver validated solutions for difficult operational problems, quickly and dependably. This paper describes a transformation program designed to meet this need and create a quantum leap in operational efficiency and service. Descriptions with lessons learned are outlined for the two components of the program—a support organization that links service delivery personnel directly with technology centers and other parts of the field and a knowledge management (KM) methodology that encourages knowledge sharing and reuse. Specifically the paper describes the program's support organization, information technology (IT) tools, processes, metrics, and change management, including training, communications, and recognition.The primary application of this enabler is to maximize the performance of field engineers by providing secure, convenient access to validated information such as best practices or to expert groups for virtual collaboration. In addition the impact on new technology development, technology sustaining, and service training and documentation has been substantial.Results have been excellent in service improvement, product development, and financial benefits.
Qualification of Two High Temperature Shearing Blind Ram Systems
Authors: Parker Bruce G. , Arora J. K. 
Published: January 2008

Abstract
Shearing blind rams are used in ram type blowout preventers to shear drill pipe, casing, tubing, and wireline cables in the wellbore. Once the above items are cut, the rams containing elastomeric sealing elements, must be able to seal and contain the wellbore pressure. This paper covers the development and testing of the elastomeric sealing elements used in two different high temperature shearing blind ram systems.
Development and Testing of a Fully Automated System to Accurately Control Downhole Pressure During Drilling Operations
Authors: van Riet E. J. , Reitsma D. , Vandecraen B. 
Published: January 2008

Abstract
Accurate control over bottomhole pressure during drilling is essential as the industry meets increasingly challenging drilling environments such narrow drilling margin formations, HPHT wells and fractured formations.
To increase the accuracy of the control over bottom hole pressures during drilling, a fully automated prototype system consisting of a hydraulics simulator, a computer controlled choke manifold and a pump as part of the mud return system has been developed and tested.
Rather than mud density alone, the system uses a reduced density mud in combination with a variable back-pressure at the annulus exit to achieve the required downhole pressure. The system is able to substantially compensate downhole pressure variations induced by the drilling operation by varying the surface back-pressure.
A number of possible advantages are associated with the use of the system: Reduction of formation impairmentReduction of mud lossesReduction of formation fluid influxIncreased ROPNo flat time during weight-up/downPotential to reduce number of casing stringsAutomatic kick circulation
A successful experimental program has been conducted on a real size test well in preparation of a field test sequence.
The system was easily retrofitted to the existing test rig and normal drilling procedures were minimally impacted.
Sand Production Prediction Study Using Empirical and Laboratory Approach for a Multi-Field Gas Development
Authors: Yeow Lei-Ming , Johar Zurita , Wu Bailin , Tan Chee , Yaakub Mohd Azriyuddin 
Published: January 2008

Abstract
A study using field and laboratory measurements to predict sand production for a multi-field gas development in offshore Peninsular Malaysia was carried out. Formation depths ranged from 1225 to 2450 metres with most of these fields having high CO2 and H2S content. Laboratory-derived properties were correlated with the openhole logs while the magnitudes of the in-situ stresses and formation pressure were derived from analysis of openhole logs, standard leak-off test data, coefficient of active earth pressure and qualitative stress information relating to the in-situ stress regime.
The sand production prediction model was calibrated against laboratory perforation collapse tests. The effect of well inclination/orientation, perforation orientation, reservoir pressure depletion and water-cut on sand production potential was evaluated. As downhole sand control increases well cost significantly and impairs well productivity, an assessment of the likelihood of sand production to decide if sand control is necessary and the timing of installation becomes very critical.
Sand production was found to be not a problem in the early part of the production of the fields with high reservoir pressures and low water-cut. Two over-pressured formations may have sand production problem with declining reservoir pressures. Based on the results of the study and expected reservoir pressures, drawdown and water-cut behavior of the fields, downhole sand control will not be required in the early stage of production.
This paper described the work done, techniques used, impact of the results of the study on the field development and benefits gained from the study.
A Case Study: Maximizing Asset Value Through Integrated Pipeline & Compression Optimization
Authors: Sutjahjo Andreas , Zainuddin Apriandy , Udianto Dewo , Wibowo Triono Hari , Hutagalung Harwan , Arifin Arifin , Prihartono Yoseph A. , Panjaitan Pahala R. , Supriyanto Herry 
Published: January 2008

ABSTRACT
VICO Indonesia is one of three East Kalimantan gas producers, and produces around 1000 MMscf/d from four main fields; Badak, Nilam, Semberah and Mutiara (Fig.1&2). VICO has also been appointed as the Gas Co-ordinator and Pipeline Custodian for East Kalimantan. The main objective of Gas Co-ordination role is to ensure reliable gas supply to the Bontang LNG plant located approximately 60kms north of the Badak Camp.
As gas fields mature, there is a requirement for the compressor utilization in each field be optimized. The optimization performed has included in field optimization, integrated intra-field compressor utilization and optimization of the East Kalimantan pipeline network. The target of this optimization is to increase gas deliverability and reserves recovery whilst minimising capital investment. In the past each asset developed its own compression strategy focused on the best value for the asset. For the last 5 years this has been expanded to include the identification of synergies with other assets, i.e. by sharing or removing idle equipment. This year, as a further development, VICO incorporated the East Kalimantan joint operated pipeline network into the optimization to determine a strategy that would give the best value for all the East Kalimantan gas producers.
The multi disciplinary study team identified excess compression capacity in one of the assets. The Field Depletion Planning model (FPM), which integrates the subsurface work program with compression and pipeline optimization, was used to identify options for utilization of this excess capacity. Each option was reviewed from the technical and economical standpoint. Gas deliverability, reserves recovery and cost are the key review parameters. The team also considered the impact on the volume of future subsurface work programs and the operational consequences.
The study recommended the installation of a small pipeline system modification to allow gas from one field to be compressed at another field. The project not only gives higher gas deliverability and incremental reserves recovery, but also allows flexibility for major pipeline contingency plans. This project is economically justified and could also provide possible future compression utilization for the neighbouring gas producers.
Malaysian Larut Drilling - Pushing the Envelope in Extended Interval Drilling
Authors: Nasir Adrin Shafil Bin Ahmad , Yaacob Zaidi 
Published: January 2008

Abstract

Summary
This paper presents a case history of a systematic approach to extending the typical open-hole section length seen in ExxonMobil Exploration & Production Malaysia Inc (EMEPMI) wells offshore the east coast of Peninsular Malaysia. Incremental improvements in shallower wells have allowed acceleration of the learning curve for use in the deeper, more complex wells. This approach was successfully completed at the Larut Platform with project wells breaking Malaysian records for open-hole section lengths and total measured depth, while minimizing the casing strings required and overall well cost.
With prior drilling experience limited to relatively shallow wells of about 4000 meters (m) measured depth (MD), there was a concern that Malay Basin formations would not support open-hole sections with lengths greater than 2200m. To meet this challenge, successive Larut wells were planned with incremental increases in open-hole section length of up to 200m. Drilling parameters were monitored and documented in these wells to calibrate predicted torque and drag values for future extended reach wells in the development program.
Drilling the first well in Larut Field resulted in little non-productive time associated with open-hole length or other related problems. As the open-hole section was systematically lengthened in subsequent wells, clean up time associated with circulation and back reaming operations at connections was optimized to compensate for the increased hole section length. Drilling data from the early wells provided credible friction factors which when used to model torque and drag in future extended reach wells did not predict any significant increase in risk for extending the open-hole sections.
The documented data in the early step-out wells allowed the team to refine and execute best practices in hole cleaning and operational practices to suit even longer hole section drilling. The Larut program successfully pushed the envelope and produced two Malaysian record breaking wells with total depths (TD) greater than 5900m initially and then 6300m, both with a horizontal displacement (HD) to true vertical depth (TVD) ratio of 2.5. The project savings associated with pushing the envelope exceeds $4,000k USD to date.
Thru-Tubing Zonal Isolation and Water Shut-Off Utilizing Coiled Tubing in the Java Sea: Operational Challenge & Treatment Strategy
Authors: Susilo Yoliandri , Hendarwin Hendarwin , Wibowo Wahju , Tobing Budhira L. , Imam Arbai , Hendra Yasri S. 
Published: January 2008

Abstract
Almost all the wells in the Offshore North West Java (ONWJ) field penetrate multi-layer reservoirs. To accommodate reservoir management issues, most of these wells were therefore completed in multiple packer completions (dual or single string with multiple packer). As the field is getting mature, more wells are becoming wet and consequently more wells are dying due to water encroachment. Therefore, remedial actions to revive dead wells play an important role to maximize the revenue. To address this issue, thru-tubing cement squeeze and polymer squeeze using coiled tubing have proved to be efficient methods to reduce water production by isolating watered out zones in the ONWJ field.
However, the operation of this job can be more complicated when done in multiple packer completion or in dual completion cases, especially when the tubing has leaks in order to avoid the cement or polymer from penetrating other places or productive zones. In several cases, the condition of old tubing that has experienced deformation (buckling/collapse) has made the task even more challenging. Therefore, treatment strategies must be designed carefully for successful cement/polymer placements into the target zone without affecting production from the other string or zones.
From 1999 to 2003, a total of 36 thru-tubing zonal isolation & water shut-off jobs utilizing coiled tubing were done with a high degree of success, although in many cases the tubing had leaks and mechanical problems. Several methods were used and modified to ensure proper cement or polymer placement. Through the use of the innovative "cement packer" technique and inflatable packer, the jobs were accomplished successfully. The coiled tubing has proven to be an effective solution to deal with well conditions in the ONWJ field.
This paper will also discuss three case histories, with each case representing different operational challenges.
Accounting for Dispersion in Injectivity Decline: Travelling Wave Flow Regimes
Authors: Altoé F. J. E. , Bedrikovetsky P. , Siqueira A. G. , de Souza A. L. S. , Shecaira F. S. 
Published: January 2008

Abstract
During the sea/produced water injection, the permeability decline occurs,resulting in well impairment. Solid and liquid particles dispersed in theinjected water are trapped by the porous medium and may increase significantlythe hydraulic resistance to the flow.
Impairment of injectors by injected/reinjected water of a poor qualitypresent a serious problem for development of oil fields submitted towaterflooding.
Similar problems occur in environmental engineering. Propagation ofbacteria, viruses and contaminants in ground water reservoirs present seriousenvironmental concerns. Design and planning of environmental protectionmeasures should be based on reliable mathematical modelling.
The particle transport in porous media is determined by an advective flow ofcarrier water and by hydrodynamic dispersion in micro heterogeneous media. So,the particle flux is a total of advective and dispersive fluxes. Transport ofparticle suspensions in porous media is described by the advection-diffusionequation and by the equation of particle capture kinetics. The conventionalmodel for deep bed filtration accounts for hydrodynamic particle dispersion inmass balance equation but does not consider impact of dispersive flux inretention kinetics.
In the present study, the model for deep bed filtration accounting forparticle hydrodynamic dispersion in both mass balance and retention kineticsequations is proposed. The travelling wave solution was found for the blockingfunction type of filtration coefficient (that becomes zero after the depositreaches some critical value). This critical value can be determined from the particle breakthrough time.
Simulation of Naturally Fractured Reservoirs Utilizing an Effective Time-Splitting and Up-scaling Methods
Authors: Sutopo Sutopo 
Published: January 2008

Abstract
The single-continuum approach employing effective permeability is one of the practical methods for simulating naturally fractured reservoirs. The mixed finite volume element (MFVE) method for full-tensor model was used to deal with permeability tensors resulted from upscaling of fractured systems.
The governing equations can effectively be formulated in fractional flow equations; i.e. in terms of global pressure and saturation equations. An algorithm is implemented applying a highly accurate numerical approach based on the MFVE method for discretizing the pressure equation, and a combination of the MFVE and the finite volume element (FVE) methods for the saturation equation. The saturation equation is discretized by means of a time-splitting algorithm that allows an explicit time stepping for FVE applied to the advection equation, and an implicit time stepping for MFVE applied to the corrective equation of capillary diffusion.
Four fracture systems comprise discrete non-crossing fractures distributed randomly. Numerical experiments of 2-D flow are presented to demonstrate the efficiency and robustness of the time-splitting technique and upscaling for simulation of fractured reservoirs.
Enhanced Oil Recovery and Elimination of Gas Coning by Using Salt Crystals
Authors: Koncz I. , Megyery M. , Szittar A. , Tiszai Gy. 
Published: January 2008

Abstract
A procedure is presented by which increased oil recovery from vertically heterogeneous reservoirs during gas flooding and/or elimination of the impacts of gas coning in gas-cut wells can be achieved. In this procedure, sodium chloride-saturated brine is injected into the layered, heterogeneous reservoir causing flood mainly in its more permeable zones. When the quantity of the solvent (water) and/or the solubility of the salt is diminished, salt crystals will precipitate in the pores of the reservoir. The crystals block mostly the more permeable parts of the reservoir which may result in reduced reservoir heterogeneity and - consequently - volumetrically more entire gas (e.g. carbon dioxide) flooding of the reservoir. The procedure, resulting in selective profile modification ensures more effective oil recovery by increasing the volumetric sweep efficiency. A field-scale project was prepared for a heterogeneous sandstone reservoir in Hungary that had been previously developed by CO2 drive. The economical estimation indicates a positive result.
Similar selective profile modification can be attained in oil-producing wells having unfavorable gas production caused by gas coning. The gas-cut pay zone can be blocked by in situ salt precipitation and the oil production of the well can be restituted. A successful gas coning elimination was carried out in the sandstone reservoir of Algyő field, Hungary. Gas coning was observed in the well, which was able to produce oil only periodically before the treatment. The well continuously produced 7400 m3 (46500 bbl) oil after the treatment including 3050 m3 (19200 bbl) excess oil recovery. In 2002, successful gas coning elimination was performed on four wells. (One of them was horizontal.) Further treatments are planned on five wells in 2003.
Thru-Tubing Zonal Isolation and Water Shut-Off Utilizing Coiled Tubing in the Java Sea
Authors: Susilo Yoliandri , Wibowo Wahju , Hendarwin Hendarwin , Tobing Budhira L. , Arbai Imam , Hendra Yasri S. 
Published: January 2008

Abstract
Almost all the wells in the Offshore North West Java (ONWJ) field penetrate multi-layer reservoirs. To accommodate reservoir management issues, most of these wells were therefore completed in multiple packer completions (dual or single string with multiple packer). As the field is getting mature, more wells are becoming wet and consequently more wells are dying due to water encroachment. Therefore, remedial actions to revive dead wells play an important role to maximize the revenue. To address this issue, thru-tubing cement squeeze and polymer squeeze using coiled tubing have proved to be efficient methods to reduce water production by isolating watered out zones in the ONWJ field.
However, the operation of this job can be more complicated when done in multiple packer completion or in dual completion cases, especially when the tubing has leaks in order to avoid the cement or polymer from penetrating other places or productive zones. In several cases, the condition of old tubing that has experienced deformation (buckling/collapse) has made the task even more challenging. Therefore, treatment strategies must be designed carefully for successful cement/polymer placements into the target zone without affecting production from the other string or zones.
From 1999 to 2003, a total of 36 thru-tubing zonal isolation & water shut-off jobs utilizing coiled tubing were done with a high degree of success, although in many cases the tubing had leaks and mechanical problems. Several methods were used and modified to ensure proper cement or polymer placement. Through the use of the innovative "cement packer" technique and inflatable packer, the jobs were accomplished successfully. The coiled tubing has proven to be an effective solution to deal with well conditions in the ONWJ field.
This paper will also discuss three case histories, with each case representing different operational challenges.
Incorporating Uncertainties in Well-Count Optimization With Experimental Design for the Deepwater Agbami Field
Authors: Narahara G. M. , Spokes J. J. , Brennan D. D. , Maxwell G. , Bast M. 
Published: January 2008

Abstract
This paper describes a methodology for incorporating uncertainties in the optimization of well count for the deepwater Agbami Field development. The lack of substantial reservoir description data is common in many deepwater discoveries. Therefore, the development plan must be optimized and proven to be robust for a wide range of uncertainties. In the Agbami project, the design of experiments or experimental design (ED) technique was incorporated to optimize the well count across a wide range of subsurface uncertainties.
The lack of substantial reservoir description data is common for many deepwater discoveries. In the Agbami project, the uncertainty in oil in place was significant (greater than a factor of two). This uncertainty was captured in a range of earth (geologic) models. Additional uncertainty variables, including permeability, fault seals, and injection conformance, were studied concurrently. Multiple well count development plans (high, mid, and low) were developed and used as a variable in ED. The ED technique allowed multiple well counts to be quickly tested against multiple geologic models. With the net present value (NPV) calculated for each case, not only was the well count for the overall highest NPV determined, but discrete testing of each geologic model determined the optimum well count for each model. The process allowed testing the robustness of any well count versus any uncertainty (or set of uncertainties).
A method was demonstrated quantifying the difference between perfect and imperfect knowledge of the reservoir description (geologic model) as it pertains to well locations.