bluuebunny/crossref_metadata_2025_split huggingface dataset:
Strategy Formulation and Balanced Scorecard Implementation Adnoc Distribution Case Study
Authors: Guidoum Mohamed 
Published: December 2007

Abstract
Strategy formulation has been the subject of numerous publications. However, smart strategies often fail due to poor implementation. The Balanced Scorecard serves essentially as a strategy implementation methodology and its role has been extended from a mere measurement framework to a strategic management system. The framework lets managers gain consensus on the organistaion's vision and translate it into strategic objectives that are supported by measures, targets and initiatives. The objectives, in turn, are grouped into four main perspectives. This paper describes a case study on the implementation of a major project of strategy formulation and implementation using the Balanced Scorecard in Adnoc Distribution.
The key findings are: 1) the design a good scorecard requires as a pre-requisite the formulation of clear strategies, 2) the involvement of managers is of utmost importance during the discussion of the vision and selection of strategic objectives, measures and initiatives, 3) commitment of management team to use it right away through reporting and linking to budget and planning cycles is necessary and 4) change in behavior of management is the result of a well-designed scorecard. Finally, the paper adds another contribution to the literature of the Balanced Scorecard which lacks publications that report practical implementation.
A Compositional Simulation of Alternative Options of a Gas Injection Project
Authors: Shi Wen , Abdou Medhat 
Published: December 2007

Abstract
Lean gas injection into the oil column has been implemented for two and half years on a portion of a giant gas-capped carbonate reservoir. Intensive monitoring has been performed on a pilot with two frequently logged observers, where gas injection rate is doubled. The major uncertainties in the original development plan were the gas breakthrough time, sweep efficiency and whether miscibility could be achieved.
The current gas injection and alternative recovery options, including enriched gas injection, double gas injection rate, conversion to water injection and WAG are evaluated by a compositional sector model. A 10-component Equation-of-State was first generated for the whole reservoir with laterally diverse phase properties by matching 48 ordinary and advance PVT tests and 4 slim-tube tests. Three nested refined local grids were utilized to focus on the key area. A realistic boundary condition adopted from the black oil full field model is utilized in history match and all prediction cases.
Production history and the latest time-lapse logging results (gas breakthrough time and saturation profiles) of the observers were matched. The simulation results reveal the severity of the vertical sweep efficiency problem of the current gas injection. No significant improvement will be made by WAG. The lean gas being injected can only reach a near miscible state with the reservoir oil. The ultimate recovery of current gas injection will not be high because of the poor vertical sweep efficiency and the strict GOR constraint.
A Unique Method for Predicting Long-Term Performance of a Mature Supergiant Kuwait Oil Field using Complex Simulation Modeling, Simple Analogies, and Classical Analyses
Authors: Carr Brian , Kumar Pradeep S. , Dashti Qasem 
Published: December 2007

Abstract
This paper describes a unique approach for estimating reservoir performance of the Burgan formation of Greater Burgan field in Kuwait, by integrating results of complex simulation modeling with simple analogies and classical analyses. The method involved first running short-term predictions with a full-field multi-reservoir simulation model, with each case focused on an individual reservoir. Simulation results were then extracted and analyzed; average well oil decline rates were developed from the extracted simulation results for each reservoir and for each area of the field. These simulator declines were used as initial declines in long-term profiling, with additional subsequent decline periods considered for long-term performance. Water production was estimated based on extrapolation of predicted oil/water ratios from the simulator, and by incorporating adjustments based on analogies. Ultimate recoveries were estimated based on analogies. Performance profiles were then generated by integrating the oil rates, water rates, and recoveries.
This paper illustrates an alternative to the over-reliance on reservoir simulation that seems prevalent in our industry. The unusual approach of combining complex reservoir simulation with simplistic analyses is demonstrated as a viable method for generating profiles of long-term reservoir performance.
Leakage is Management by a New Sealing System for Twin-Screw Multiphase Pumps
Authors: Brandt Jens-Uwe , Müeller-link Dietrich , Rohlfing Gerhard 
Published: December 2007

Abstract
Multiphase Pumping is recognised as state-of-the-art technology. But still operators and manufacturers see themselves confronted by two major challenges which are first the set of operating parameters, and second the Mean Time Between Failure.
The mechanical seal system strongly contributes to the MTBF, hence this has been subject to various brainstorming with all parties involved.
Modern "Multiphase Boosters" have little in common with standard pumps or compressors as far as operating parameters are concerned. All parameters especially effecting the seals are of a transient character while those in pumps or compressors are quasi-static.
This paper presents a new sealing technology, which keeps any process liquid inside the pump, with emphasis on experience gained in test-bed runs and field operations.
Electrification of Gas Well Production System Reduces Operational Costs in Saudi Aramco Gas Field
Authors: Rivenbark Mark , Khater Sami , Barnes Steven , MacKenzie Roy 
Published: December 2007

Abstract
A major Middle East operator has been producing gas from the same formation for approximately 20 years, using conventional hydraulic actuators to control wellhead gate valves. These actuators have been operated from a hydraulic control panel that is pneumatically powered, and the compressors used to generate the instrument air have been electrically driven. Although the actuators have been able to perform satisfactorily in controlling the wellhead gate valves, the operations have not been cost efficient for several reasons. First, the pneumatic/hydraulic control systems have been maintenance intensive. Secondly, electricity has been required to run air compressors to power the hydraulic actuators.
Recently, the operator began a five-year drilling program to develop additional gas reserves, and as part of this process, decided to investigate alternatives to existing well-site equipment. One of the primary requirements of the new equipment was that it reduce operating costs. Areas targeted to provide the savings would be:
The current levels of equipment maintenance and related manpower needs Equipment integrity against the environmental conditions inherent to the area (blowing sand, heat, rain, etc.) Environmental safety.
This paper will discuss a first-of-its-kind all electric system using electric gate-valve actuators, an electric control panel with PLC logic controller as well as electric pressure pilots, electric fusible plugs, electric emergency shut-down (ESD) switches, and a battery back-up system that was developed for this installation.
An existing well was converted to the system, and a rigorous one year testing program was carried out by the operator. In addition to normal exposure to the elements and routine opening and closing of the well to meet production demands, the test also included over 300 additional open and close cycles on each of the 3 electric actuators on the tree. After conducting the test program, the operator estimates that capital cost savings for the all electric system could be in excess of $200,000 per well over the present pneumatic/hydraulic systems. Additional savings in manpower and maintenance are also anticipated.
Twister Supersonic Gas Conditioning Process
Authors: Okimoto Fred T. , Sibani Salim , Lander Michael 
Published: December 2007

Abstract
Twister Supersonic Separator is an innovative and revolutionary gas processing system. The Twister technology was developed by Shell. Twister B.V. was launched as a separate company in April 2000 by Shell Technology Investments Partnership, a 50/50 venture between Shell and the Beacon Group. Twister Supersonic Separator is the resulting synergy from combining aero-dynamics with the traditional gas processing concepts of thermodynamics and fluid dynamics. Twister is based on the following concepts (Figure 1):
– Gas is expanded in a Laval nozzle to supersonic velocities with resulting lower temperatures. – Nucleation of water and hydrocarbon occur, followed by growth of liquid droplets. – The gas and liquid droplets enter the wing section, where a very high swirl is created and the liquid droplets are centrifuged onto the walls, creating a liquid film. – The gas and liquids are separated in the drainage section. – Pressure is recovered in the diffuser section, to about 7080% of the initial pressure.
This is done without chemicals or rotating equipment, and requiring minimum space and weight, thus saving significant capital and operating costs.
Managing Onshore Drilling Wastes – Abu Dhabi Experience
Authors: Mokhalalati Talal , Al-Suwaidi Abdullah , El-Fatah Hendi Abdul 
Published: December 2007

Abstract
When drilling fluids and cuttings are discharged into the ground, the liquid fraction including any dissolved chemicals begins to enter and travel through the soil bore. Contaminants can reach groundwater, dissolve into it and be transported to other horizons. Very small solids, heavy metal can also be transported to the ground water although the porous media will filter large particles.
Spilled or improperly disposed drilling wastes have the potential to harm plants and animals, it should be managed to minimize risk to human health and the environment.
The paper describes how Abu Dhabi Company for Onshore Oil Operations (ADCO) handled the various drilling-related wastes. It provides information on some of the cost-effective techniques utilized to tackle the major drilling wastes, these include:-
Drilling fluid system and related rig equipment have been modified with waste minimization in mind. Mud chemical products have been substituted with less toxic substances. Oil based drilling fluid has been used in multi-wells prior to being permanently injected downhole. Oily drilled cuttings are treated by thermal desorption technique, slurrification and injection downhole, or transported to central waste plant. High salinity water based drilling fluid is injected downhole Acid used during well testing is neutralized prior to disposing. Flaring oil during well testing is eliminated either by flowing to station or trucking. Free gas is flowed to production facilities and flared only when operations dictate. Other options such as biological treatment are in the study phase.
The paper summarize the experience ADCO gained to date during the operations of minimizing environmental impacts on five major onshore fields operated by the company.
Environment Protection in Oil and Gas Industry: A Gateway to Sustainable Development
Authors: Drapier Maurice , Sutton Catherine , Morillon Anne 
Published: December 2007

Abstract
During the last two decades, people began to realise that we cannot have a healthy society in a world with environment degradation. The development that human kind achieves nowadays makes more and more urgent the need to implement sound and appropriate environment protection measures and to plan a concerted and controlled use of raw materials.
On it's part, the United Arab Emirates, aware of its very sensitive natural areas and singular environment, has organised since 1998 numerous symposiums aimed at sharing experience in the field of wildlife protection. Abu Dhabi Oil Operating Companies, each one in its own way, have been active partners in a progressive effort that highlights the role of environment conservation in their operations.
Among them, Total Abu Al Bukhoosh, like most of the Group subsidiaries (TotalFinaElf is the new name of Total Group after the mergers with Petrofina and Elf), has developed since 1992 an environment management plan whose goal is to identify, control and decrease polluting emissions to the environment resulting from exploration and production activities. In this way, the environment protection is a key point in our practice, an obliged gateway where shareholders, employees and customers must feel our strong concern for conserving our environment.
Corrosion Monitoring in Mauddud Pilot Wells in North Kuwait Oil Fields: Data Analysis, LPR/pH and Downhole ESP Relationships, Problems and Solutions
Authors: Al-Aqeel Zaid A. , El-Shourbagi Said M. , Mousawi Ahmed Z. 
Published: December 2007

Abstract
Water Flood Pilot (WFP) Projects were started during June 1997 in two of North Kuwait's major oil fields to determine the feasibility of waterflooding the Mauddud Carbonate Reservoir.
In each of the two pilots, the injection water supply comprised source water well, completed with a downhole electrical submersible pump (ESP) across the underlying Lower Burgan aquifer. Source water rates of up to 10,000BWPD were pumped from the well to a surface booster pump, designed to deliver an injection pressure of 2000 psi at the injection well.
A significant part of the feasibility study was monitoring system corrosion. Specific surface measurements included pH, total suspended solids (TSS), corrosion rate derived from Linear Polarization Resistance (LPR) and concentration of injected corrosion inhibitor. This suite of data and associated interpretations are presented and discussed. The data recorded also documents radical fluctuations in LPR and pH measurements several days before ESP failures.
Downhole corrosion in producers experiencing breakthrough of injection water is also examined through a sequence of Wireline Micro Vertilog (MVRT) interpretations. Corrosion rate variations relative to produced watercut are presented.
In addition, the application of chemical inhibitors and plastic coated surface and downhole tubular are discussed relative to managing the conditions experienced. Finally, the collation of this daily data over a two-year period enables conclusions to be drawn regarding optimum sampling procedures and the advantages and disadvantages of the water system used.
The collection of data during this project has resulted in significant learning, some of which is transferable to other waterflood operations. Significant technical contributions are made on corrosion monitoring and inhibition, MVRT interpretation and surface sampling.
High Oil Recoveries from Transition Zones
Authors: Masalmeh Shehadeh K. 
Published: December 2007

Abstract
Oil-water transition zones may contain a sizable part of a field's STOIIP, specifically in low permeable sandstone and carbonate reservoirs. The amount of recoverable oil in a transition zone depends–among other things- on the distribution of initial oil saturation (Soi) as a function of depth and the dependency of the oil's mobility, i.e., the residual oil saturation (Sor) and relative permeability, on initial oil saturation.
In this paper we present laboratory measurements of residual oil saturation and oil relative permeability as a function of initial oil saturation to properly characterize oil mobility in transition zone. We found that the residual oil saturation after water flooding showed, for the example studied here, no dependence on initial oil saturation. On the other hand we found that there is a clear trend in the imbibition oil relative permeability for decreasing Soi, i.e., for a given oil saturation oil mobility increases as initial oil saturation decreases. In other words, laboratory measurements show that the mobility of oil in the transition zone is much higher than conventional analysis would suggest. Consequently, in a given time span more oil can be produced from the transition zone than generally assumed and potentially large volumes of reserves can be added to reservoirs with large transition zones.
The impact of the measured relative permeabilities and residual oil saturations on oil recovery has been quantified for a generic field example by numerical modeling using MoReS, the Shell group reservoir simulator. The recovery factor was found to increase from 32% using a single set of relative permeability curves for the whole field independent of initial oil saturation to 56% using the measured Soi dependent relative permeability curves. The water cut at abandonment was for both cases taken at 95%.
Analysis of a Fractured Carbonate Reservoir (Thamama Group) Using Borehole Images From an Horizontal Well, Offshore UAE
Authors: Williams P. D. , Maddock R. H. , Sapru A. K. , Lawrence M. J. F. 
Published: December 2007

Abstract
Structural analysis has been performed on borehole resistivity images from a horizontal well through the Lower Cretaceous Thamama Group carbonates, offshore UAE, in order to investigate structural compartmentalisation within a complex faulted reservoir.
The study interval has been divided into four major Borehole Image Units on the basis of borehole image and openhole log response. The contacts between these units include bed boundaries and faults. Within these units, both electrically conductive and resistive stylolitic bed boundaries were identified.
Faults and fractures with varying appearance and extent along the wellbore are identified from the borehole image log. These features were classified by their electrical response and image appearance. Faults were discriminated from fractures by evidence of offset, interpreted lithological juxtaposition and greater thickness. Resistive fractures, interpreted as cemented, may act as baffles to fluid movement. Conductive fractures, interpreted as having aperture filled by (electrically conductive) drilling fluid, may act as fluid pathways. Fractures with a mixed electrical response on the images may be vuggy.
Fractures occur as clusters along the wellbore, with increased fracture intensity within damage zones associated with some faults. Clustering of conductive fractures is due to both tectonic and litho-stratigraphic factors. Resistive fractures show a dominant NW-SE strike, and conductive fractures show a dominant NE-SW strike. NE-SW to ENE-WSW striking fractures are under-sampled because of the borehole orientation (SW). The strike of conductive fractures is broadly similar to the regional direction of the maximum horizontal stress.
Reservoir pressure data correlate with the Borehole Image Units and the distribution of resistive faults. Resistive fault boundaries support modest static fluid pressure differences and are interpreted to isolate three reservoir pressure compartments.
Effective Mineral Scale Control in Canyon Express, Gulf of Mexico
Authors: Yuan M. , Smith J. K. , Cooley C. , Williamson D. A. 
Published: December 2007

Abstract
In deepwater subsea oil and gas production, methanol is commonly used for preventing gas hydrate formation. Other than some recent laboratory experiments on the effect of methanol on mineral scale precipitation,1&2 there however have been no field reports of methanol-induced or aggravated mineral scale deposition in the oilfield produced fluids. This paper presents a unique and severe calcium sulfate (gypsum) scale deposition problem in the Canyon Express field system, a deepwater subsea tieback in the Gulf of Mexico, and its successful inhibition by using methanol soluble scale control products. In this case, the gypsum scaling was found to be directly caused by continuous injection of large volumes of methanol into the produced fluids for hydrate inhibition. This paper describes and discusses this particular scale problem, its diagnosis, computer prediction of methanol effect on scale formation, qualification of a methanol soluble combination scale/corrosion inhibitor, and the subsequent successful inhibition treatment of the gypsum scale. This paper highlights the drastically detrimental impact of methanol on scale formation and demonstrates the benefits of using methanol soluble scale control products that reduce the need for additional subsea injection lines and eliminate the potential for chemical incompatibility.
The Development and Application Offshore of a Direct Test of Well Fluid Scale Inhibition
Authors: Collins Ian R. , Chilcott Neil P. , Thornton Alex 
Published: December 2007

Abstract
Where wells are protected by scale inhibitor squeeze treatments, it is critical that there is an effective means of determining whether the produced fluids are inhibited against scale formation. Conventionally this is achieved by determining the minimum concentration of inhibitor required to prevent scale formation in the laboratory and then taking wellhead samples which are sent to an offsite laboratory for analysis to determine the concentration of inhibitor that they contain. Whilst this method can be an effective monitoring technique for inhibitor concentrations in excess of the minimum inhibitor concentration (MIC), it can introduce risk when wells are close to the MIC owing to the time required to turn around samples. Additional problems arise with poor sample preservation and the often-low frequency of sampling. A more robust approach to managing producing well scale risk is to utilise an on-site test that can be simply performed on freshly taken wellhead samples. The greatest value arises from a test, moreover, that is independent of laboratory determined measures of scale inhibition effectiveness.
In this paper we report the development, field validation, and routine application on the Miller Field in the North Sea of a direct test for the degree of scale inhibition exhibited by wellhead samples. The test, as described, relies upon the stressing of samples with excess barium or sulphate ions and the monitoring of turbidity developed in the solution. In contrast to other stress tests that have been reported previously, the test described relies upon simple robust equipment and is straightfoward to perform allowing samples to be taken routinely and monitored in near-real time.
The recent introduction of the stress testing technology on the BP operated Miller Field has already provided significant rewards with respect to HSE and scale management in one of the harshest barium sulphate scaling environments in the world.
Effect of PPCA and DETPMP Inhibitor Blends on CaCO3 Scale Formation
Authors: Chen T. , Neville A. , Yuan M. 
Published: December 2007

Abstract
PPCA and DETPMP are two common commercial scale inhibitors used to control mineral scaling in the oil and gas industry. Normally, PPCA is regarded as a nucleation inhibitor and DETPMP as a growth inhibitor. In this paper, the effect of PPCA and DETPMP blends on the inhibition efficiency of calcium carbonate scale formation is presented.
In this paper, calcareous scale formation was studied both in the bulk solution and on the metal surface in supersaturated scale formation solutions, which represent typical waters encountered in oil and gas production. The effect of inhibitor blends on scale formation is studied. It shows that the inhibitor has a different inhibiting effect on precipitation in the bulk solution and deposit formed on the metal surface and reasons for this are discussed. It also demonstrates that bulk precipitation and surface deposition are two different processes and both processes should be studied to completely understand an industrial scaling system.