bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design Considerations for a New High Data Rate LWD Acoustic Telemetry System
Authors: Shah Vimal , Gardner Wallace , Johnson Don H. , Sinanovic Sinan 
Published: December 2007

Abstract
The first commercial acoustic telemetry system was successfully introduced in 2000 as part of a drill stem testing system. However, environmentally challenging LWD offshore applications and a need for higher throughput required a complete redesign of that system. Thus, the new system incorporates a new high power acoustic transmitter driven by an advanced signal processor that maximizes input energy into particular frequencies and therefore minimizes dispersion and distortion effects. Low-frequency acoustic attenuators were specifically designed to attenuate in-band noise entering the communication system. In addition, two other features were introduced as a part of the complete communication system. They were (1) an in-line wireless link to pickup, digitize, and transmit signals off the pipe while rotating and (2) a high data rate acquisition and telemetry processing system. The system is designed to work solo or in conjunction with a mud pulse telemetry system. This paper will discuss the system design considerations and the data rates associated with different modes of operation as well as results of initial field tests.
Obtaining Formation Water Chemistry Using a Mud Tracer and Formation Tester in a North Sea Subsea Field Development
Authors: Hodder M. H. , Magdy Samir , Holm G. , Segret G. 
Published: December 2007

Abstract
Precipitation from and corrosion by formation water co-produced with target hydrocarbons can cause serious problems, and an early knowledge of water chemistry is important for completion and facilities design. Owing to the high cost of interventions, this knowledge is particularly important in deepwater developments and subsea completions.
Samples of formation water are obtained by producing from the well completed in the water leg or sampling after water production occurs naturally. The former method carries significant cost and the latter method may delay the knowledge of the water chemistry.
Alternatively, a formation tester can be run into the wellbore to collect small samples directly from the formation.. In wells drilled with water-based mud, the results are generally mixed because successful collection of formation water requires that the tool be able to discriminate between the water and invaded filtrate. The method depends on the contrast in color or resistivity between formation water and water-based mud filtrate to determine when it is collecting water, and this contrast often doesn't exist.
This paper presents a new solution. A mud tracer was used to change the optical properties of the mud filtrate to make it detectable downhole. Laboratory experiments checked the compatibility of the tracer with gypsum or glycol mud system, sensitivity to high clay content, and ability to be detected with another tracer, and individually and in combination with a dark-colored filtrate. Shop experiments were carried out to establish a relationship between different tracer concentrations and optical properties at specific wavelengths. This relationship represents the basis of tracer detection and contamination prediction in real time downhole.
The first trial was carried in the Otter field in the northern North Sea. The field comprises three producers and two injectors with subsea completions. Downhole water samples were obtained during the logging phase on one of the injectors at an early stage of the field development. Sample quality and flushing time were optimized using the new technique. Sample analysis results compared well with later production tests.
Multiphase Flow Helico-Axial Turbine: Applications and Performance
Authors: Charron Yves , Pagnier Philippe , Marchetta Elise , Stihlé Sylvain 
Published: December 2007

Abstract
Following the installation in production fields of several tens of Two Phase Helico Axial Pumps, IFP and DBGP have recently launched a R&D program for the development of Two Phase Helico-Axial Turbines. These turbines may be used in many process applications in replacement of let down valves for energy recovery but also to increase the cooling duty or the liquid production. They may also be used in systems including a two phase separator with single phase expanders / turbines in view of reducing the number of equipment, space and weight. These turbines, suitable for all gas fractions, may find applications in the production of hydrocarbons (HP/HT wells, fractured reservoirs, oil stabilisation, electricity production in remote areas) but also in hydrocarbon treatment or in gas liquefaction. These applications cover a broad range in flow rate, pressure, temperature, gas fraction and fluid composition. A two phase helico-axial turbine prototype has been tested during the present year confirming the expected hydraulic performance. The hydraulic efficiency was found satisfactory to provide significant energy and liquid recoveries in many applications.
Toucan Smart Field Development: How to Generate More Value from Hydrocarbon Resources
Authors: Braithwaite S. R. , Müssig S. , van der Poel R. , van Putten S. , van de Waal W. , Kass M. 
Published: December 2007

Abstract
The Toucan Field is an oil rim situated in Gabon, discovered late 2001, operated by Shell Gabon. The joint venture partner is Amerada Hess Production Gabon. Experience from an adjacent field indicates that it is critical to manage the oil rim in such a way that reservoir energy is preserved whilst maximizing oil production. Due to the limited amount of information in this early stage of field development, there is high uncertainty in terms of reservoir properties. The smart technologies applied are directed towards reducing these uncertainties and mitigate down side risks of structural uncertainties.
Firstly a smart well completion is described which permits control of drawdown in long horizontal wells where total drawdown must be restricted owing to the proximity of water and gas. The completion instrumentation allows the flow control valve to be positioned using pressure rather than positional information. Based on simulation work, various strategies for well operation are discussed, along with their various merits; both in the context of the well, and the field.
Secondly the combination of frequent well tests, production optimization, and the use of reservoir surveillance tools is used to deliver an optimal solution to help the asset team analyze deviations from the expected reservoir performance. The business benefits of these smart technologies are discussed in the context of implementation in a medium sized oil rim.
Portfolio Analysis for a Bundle of Oil and Gas Projects
Authors: Al-Thani F. F. J. 
Published: December 2007

Abstract
Projects are now being procured or considered in bundles rather than on an individual, stand-alone basis. For the purpose of financial analysis, bundled projects can be considered as portfolios of projects. When projects are considered individually, some may be commercially viable as stand-alone projects and others may not. However, when projects are bundled together, an overall portfolio of projects may meet the promoters Minimum Acceptable Rate of Return (MARR) and be deemed commercially viable. This paper describes the mechanism and software used to assess a portfolio of small oil and gas projects, those being new projects and the refurbishment and operation of existing facilities. This paper describes how a non-commercially-viable batch of refurbished facilities can be financed with the help of cross collaterisation from the commercially viable batch of new projects when considered as a portfolio.
The First Real Zero Gas Flaring Project in the Middle East and Gulf Region
Authors: Wasfi Adel K. 
Published: December 2007

Abstract
The ADNOC group operating companies have over the last few years worked hard to progress towards the company's "Zero Flaring" aspiration. For the first time, within the ADNOC Group and GCC countries, a true Zero Flaring system is now in operation. The previous continuous Flow Suction Tank (FST) flare in one of ADCO's major fields is now completely switched off during normal operation.
This historic milestone resulted in 90% reduction of the Field's total daily process flaring (from about 2.8 MM scfd to 0.3 MM scfd).
On an annual basis the closing of this FST flare results in additional gas being made available to ADNOC, about 900 MMscf worth 1.4 MM$. The total combined value from environmental benefits and recovered gas is $22million over a 25 years period using Net Present Value calculations.
The challenges faced were the following: Recovery of flash gasElimination of gas blanketingElimination of hydrocarbon purge gasElimination of pilot gasHigh H2S gas content and related safety issues.
The implemented solution included: A vapor recovery system using an oil injected screw compressorA high integrity Quick Opening Valve (QOV) in the existing 30 inch flare header.A new high integrity continuous sparking ignition systemControl and monitoring system: –to guarantee quick opening of the QOV–Provide online status information of the QOV and the automatic ignition system.N2 generation package for the continuous purge of the flare header with automatic fuel gas purge as back-up.New flare tip to suit the new operating conditions.Ultrasonic flow meter to measure the gas being sent to flare.
Comprehensive Solutions to Drilling Waste Management
Authors: Al-Suwaidi Abdullah , Hun Christian , Marmash Fuad , Hendy Abdel Fatah 
Published: December 2007

Abstract
ADCO has always been seeking continual improvement to minimise the impact of its drilling operations on the environment and to conserve the desert for future generations. One of the main challenges is proper management of the fluids & solids generated by drilling oil & gas wells.
This paper presents the complete solutions adopted to handle the generated waste streams with the improvements in rigs design ("zero" discharge) and the execution of three recent plants: Reconditioning & recycling plant for drilling Oil-Based Mud (OBM).Indirect thermal desorption treatment plant for OBM drill cuttings with 100% recycling of recovered materials which are converted to usable products (i.e., diesel fuel, irrigation water and interlocking blocks).Two dedicated deep disposal wells for waste mud.
The outcome of the joint efforts of Drilling & HSE Divisions confirms that all hazardous wastes are being managed with true applications of 3R (Reduce, Reuse and Recycle) to maximise hydrocarbon recovery without noticeable impact on the environment.
The new waste management plants are centrally located in the major oil producing fields, thereby reducing hauling distance. These improvements translate in ADCO to minimum disposal and overall costs saving while ensuring compliance with or even exceeding, local environmental regulations.
Such global approach of this scale is a first in the Middle East Region and is setting a new benchmark of environmental standards for others to follow.
The Effect of Diffusion on the Saturation Pressure of Fractured Oil Reservoirs
Authors: Mohebbi A. , Rahimi A. 
Published: December 2007

Abstract
The role of diffusion in reducing the saturation pressure of oil in blocks located at different depths of fractured oil reservoirs has been studied. A model to describe unsteady state diffusion in a matrix block with a given geometry in fractured oil reservoirs has been developed and the results have been compared with the analytical solution. The delay time for solution gas drive due to diffusion in a block with a given shape has been calculated by using the data of Haft kel field.
Petrophysical Models and Techniques for Shaly-Sand Formation Evaluation
Authors: AlRuwaili Saleh B. , AlWaheed Hilal H. 
Published: December 2007

Abstract
Conventional petrophysical models, e.g. using neutron-density cross-plot for lithology and porosity and Archie's equation for water-saturation, can be adequate for evaluating clean sands, which have null or minimal shale and clay. Moreover, routine core analysis can be enough for validating log-analysis results in clean sands. On the other hand, shaly-sand formations have shale and clay present in them and the above standard petrophysical techniques are not adequate for the accurate evaluation of shaly-sand formations. Porosity logs, e.g. neutron, density and sonic, and saturation logs, e.g. deep-resistivity, are affected by clay presence in shaly sands. Such effects need to be modeled and incorporated in the log analysis in order to obtain more accurate formation evaluation of shaly sands.
Some of the hydrocarbon-bearing formations in Saudi Arabia have shaly sands. Soft and hard data was acquired to help evaluate and describe the storage and flow capacities of these formations for optimal production developments. Density, neutron, sonic, resistivity and gamma-ray logs were routinely acquired in wells drilled in these formations. Logs like Elemental-Capture-Spectroscopy (ECS) and Nuclear-Magnetic-Resonance (NMR) were acquired in key wells. In these shaly formations, some wells were cored and core analyses were conducted to obtain formation porosity, electrical properties and clay attributes like clay-type and clay-abundance. The above soft and hard data acquired has helped in developing and applying more reliable petrophysical models and techniques in shaly sands formation evaluation.
This paper will present and discuss methods and modeling techniques for evaluating shaly sands. Applications of these techniques in some shaly formations in Saudi Arabia are included in this paper.
Integration of Impedance Inversion Results into the IRAP 3D Geomodel
Authors: Al Mehairi Y. , Al Khowaildi S , Al-Shaikh Ahmed , Chenot D. , Pizza J. L. , Prat P. , Lalande S. , Barens L. , Hegre J. A. 
Published: December 2007

Abstract
This paper describes the final part of a joint integrated seismic characterization project on a major carbonate reservoir of an onshore field, in the Middle East. The reservoir geomodel building captures well information, the 3D structural and seismic information obtained through seismic interpretation and impedance inversion.
The aim of this seismic characterization project was to improve the reservoir management by optimizing well placement, geosteering and geomodeling. These goals imply to derive the lateral and vertical heterogeneities in the reservoir and to characterize the reservoir porosity variations including the location and volume of some non-reservoir ‘dense’ bodies embedded in it.
Stochastic inversion was carried out with in house software Geolnv™ The stochastic approach enables us to compute a family of equiprobable impedance inversion volumes that are both constrained by seismic and well data. For this inversion, a family of 100 realizations was computed using 22 input wells and a mean wavelet that extracted on 6 high quality wells. Each inversion contained 785 000 traces.
Contribution to the valuation of Microseismic monitoring data recorded from treatment well – Results based on 20 hydro-fracturing jobs recorded from treatment well
Authors: Kaiser P. , Fortier E. , Gaucher E. , Maisons C. 
Published: December 2007

Abstract
To stimulate their oil recovery, oil companies carry out hydraulic fracturing jobs. In this aim the characterization of the fracture, as fluid path, is crucial. It is no longer necessary to prove that the microiseismic monitoring of hydro-fracturing experiments can be used for fracture mapping. Nevertheless, monitoring from treatment well is still a challenge. Using the field experience gained over 20 jobs, we present here a review, as objective as possible, on microseismic monitoring performed during fracturing operations from the injection well (treatment well). Over these last five years, we managed to collect a significant database/catalogue of frac jobs monitoring results, yielding us to keep learning, step by step. Various configurations of the tools in the reservoirs and various probes were experienced. The stimulation jobs were carried out in different types of overburdens, and various behaviours of the formations have been observed. The reservoir behaviour lead to fracture mapping and characterization in successfull cases; however, unconsistent acoustic response was also detected. This is all this feedback we now present here, keeping in mind that these assessments are to be seen just as a starting point within an ongoing learning process.
Can Cement Log be Better Managed and Analyzed
Authors: Talabani Soran 
Published: December 2007

Abstract
Whether cement exists behind casing or not is easily identified by the current generations of cement evaluation tools. However, there are few important questions to be seriously taken into account once analyzing cement log for zonal isolation; is the cement attached to the casing? Does the cement isolate different beds and zones? Does any micro or macro annulus exist over intervals of interest? And if so, does it affect on the well future. Is the cement attached to the formation preventing micro or macro fractures? Does capillary have any effect on the cement integrity? How the width of this micro-crack be measured. And the last, do gas and other fluid seep through the micro-channel.
Looking at cement log might be easy, though not the analysis. Analysis of the cement bond tool data is very crucial for forthcoming decisions on a well. Therefore, it is important to identify cement quality. Some micro-channels might behave as a barrier to prevent any fluid movement, while other good cement body might create cracks soon after the well is set on production. There are some identical cement jobs that results in very different isolation results! So, why this happens? All these have answers once cement log is quantified and later analyzed.
In this paper, case histories are addressed in both, poor and fair cement jobs behind casing. In the field examples, the effect of tool centralization on the log quality, the means and ways of identifying micro and macro channels, and possible remedy based on correct cement log evaluation and analysis are addressed.
Interpretation of Multiple Hydraulically Fractured Horizontal Wells
Authors: Zerzar A. , Tiab D. , Bettam Y. 
Published: December 2007

Abstract
Horizontal wells are ideal in tight reservoirs where economic production cannot be achieved by conventional vertical wells. One of the advantages of a horizontal well over a vertical well is that it can be fractured at a number of positions along its horizontal section. Tight reservoirs generally produce in transient state for a considerable part of their producing life. Therefore accurate transient inflow models are required, not just for well testing purposes, but also for production forecasting. The objective of this study is to determine the number and characteristics of the producing fractures along the horizontal segment of the well.
A new analytical model is developed to describe the transient pressure response of a horizontal well intersected by several fractures in anisotropic reservoirs. The fractures along the horizontal wells are assumed to be rectangular and vertical, and either transversal or longitudinal relative to the well direction. They are also of finite conductivity, infinite conductivity, or uniform flux type. It is further assumed that the fractures are fully penetrating (2D Model) or partially penetrating (3D Model), the well is either open or perforated only at fractures.
A new set of type curves are developed that include five flow regimes: Bilinear, Linear, Radial, Biradial, and Pseudoradial. New equations have been developed describing the unique characteristics of the five flow regimes. These equations allow us to calculate: the number of active fractures, equivalent fracture conductivity and total system conductivity, equivalent half-fracture length, reservoir directional permeabilities, equivalent skin, and the total skin of the system without using type-curve matching. A step-by-step procedure is provided for calculating reservoir parameters of a multiple hydraulically fractured horizontal well and practical applications are carried out by solving some simulated examples.
Vertical Conformance in a Mature Carbonate CO2 Flood: Salt Creek Field Unit, Texas
Authors: Bishop Deborah L. , Williams Mike E. , Gardner Stephen E. , Smith David P. , Cochrane Tom D. 
Published: December 2007

Abstract
Salt Creek Field Unit is one of many mature carbonate reservoirs first waterflooded then CO2 flooded in the Permian Basin. The reservoir consists of multiple layers of porous, grain-dominated shoals with varying permeability and porosity, separated by non-porous layers of varying thickness. The different properties of the layers result in different processing rates and times. As CO2 floods mature and production declines, operators are challenged to maintain efficiency. At Salt Creek this is accomplished by tracking the maturity of each zone, calculating the contributions of each, and modifying the completions to optimize oil production and profitability.
Salt Creek Field Unit was discovered in 1950 and water injection began in 1953. The waterflood was modified several times and by the early 1990's, the field was developed on 20-acre spacing with five-spot patterns. In 1993, a CO2 WAG (Water Alternating Gas) flood was implemented, whereby water is injected alternating with gas (CO2). Consistently optimized reservoir management practices including geologic modeling, zonal injectant tracking, and 3-D seismic have added great value to the field and have created an environment where flood optimization efforts continue to be profitable.
One of the key processes enabled by effective reservoir management is the ability to identify mature (swept) layers and identify workover candidates. First, injection data is allocated based on interpretation of injection profile logs and stored in a database that calculates zonal maturity as a fraction of hydrocarbon pore volume injected. A type curve relating CO2 injection to incremental oil recovery is calibrated to match current pattern production. Post-workover production is then predicted based on the recovery curve applied to the remaining targeted intervals. The resulting production is adjusted for incremental CO2 injection enabled by the workover, changes in producing bottomhole pressure, and gas plant capacity limitations. Where economics are favorable, recommendations are made to modify the wellbore's profile with plugs, cement squeezes, straddle packers, or, where casing is particularly poor, with liners. The result is a more effective use of a valuable injectant and a more profitable lease.