bluuebunny/crossref_metadata_2025 huggingface dataset:
Microbial Water Treatment: An Alternative Treatment to Manage Sulfate Reducing Bacteria (SRB) Activity, Corrosion, Scale, Oxygen, and Oil Carry-Over at Wilmington Oil Field - Wilmington, CA
Authors: Cassinis Richard B. , Farone William A. , Portwood James H.
Published: December 2007

Injection water is commonly treated with chemical biocides, corrosion and scale inhibitors, and oxygen scavengers, to name a few. Without treatment, iron sulfide, hydrogen sulfide, iron oxide, and other impurities will form, precipitate and damage unprotected surface equipment and lines and plug injection wells. In many cases, acid, xylene and even coiled tubing are required to restore injectivity.

Although traditional chemical treatments can be effective in many cases they are not "worker friendly". This paper will present the results of an ongoing, worker and environmentally safe, lower- cost alternative-Microbial Water Treatment (MWT). A discussion of treatment mechanics, strategies and evaluation are presented along with past and current results of the successful 310,000 barrel per day MWT program at the Wilmington Oil Field.

P. 435
Safety and Environmental Performance Measures in Offshore E & P Operations: Empirical Indicators for Benchmarking
Authors: Iledare Omowumi O. , Pulsipher Allan G. , Mesyazhinov Dmitry V.
Published: December 2007

Several indicators—such as the fire/explosion incident rate, blowout incident rate, oil spill incident rates, production incident rates, and drilling incident rates—have recently been formulated by an industry working group (PMWG) to facilitate the evaluation of environmental and safety performance of OCS operators. In this paper we have attempted to quantify some of these measures using data from an existing Minerals Management Service (MMS) events file for the period 1987-1993. Similar measures such as a relative safety index, nominal accident rate, spill rate, injury rate, fatality rate, and weighted safety score—developed at Louisiana State University's Center for Energy Studies (CES)—are compared to PMWG indicators. Our comparisons of CES performance measures and the PMWG measures, for which data is available, show little difference with respect to the relative performance of small and large independents and majors when considered as groups.

This result strengthens our earlier conclusions that the historical record does not support the concern that the expanded role of independents on the OCS poses any significant danger to safety or the environment in the Gulf of Mexico region.

P. 451
Field Trial of a Multiphase Flow Meter
Authors: Mohamed Peria G. , Al Saif Khaled H.
Published: December 2007

A Multiphase Flowmeter (MPFM) was installed in series with a conventional well testing system (test separators and test tank) at an operating field in Kuwait. The MPFM employs a positive displacement meter, a venturimeter and a microwave sensor to measure the flow of total fluid, gas and water respectively. A bypass loop with a vortex shedding flowmeter enables measurement of a large range of gas flow rate. A number of wells covering a wide range of Production rate (680 to 6130 bpd), Gas Oil Ratio (207 to 889) and water cut (0-65%) were tested. The comparative results are presented. The MPFM results are more accurate, and more consistent than those of conventional system and allows faster well testing. An insight into the behavior of MPFM at varying field conditions and useful information on issues related to range and accuracy are presented. Useful hints to those companies interested in testing/procuring Multiphase Flow meters are also presented.

P. 471
Field Case: Cyclic Gas Recovery for Light Oil-Using Carbon Dioxide/Nitrogen/Natural Gas
Authors: Miller Bernard J. , Hamilton-Smith Terence
Published: December 2007

Cyclic gas recovery ("Huff and Puff") using carbon dioxide has been applied successfully in the Big Sinking Field of eastern Kentucky.

The process was initiated in 1986, and was used continuously until 1994, with 390 treatments on 240 wells. A total of 12,200 tons of liquid carbon dioxide resulted in additional recovery of 180,000 barrels of oil. Successive cycles became less efficient, and a changing market for liquid carbon dioxide resulted in a 50% increase in price. The process was continued with rich gas (1900 Btu casing head) and exhaust gas (80% nitrogen and 20% carbon dioxide).

Both gases were tested in two separate areas of the field where cyclic carbon dioxide had been performed successfully. In both cases the gas channeled within days to offset wells with little incremental recovery. The offset wells affected were located in the northeast/southwest natural fracture trend. The offset wells were shut in and allowed to soak and the input well was shut in after the designated volume was injected. Both the input wells and the offset wells had production increases. The exhaust gas increased the production six times over the initial production rate, and after two years of production response, the estimated ultimate recovery is O.85MCF/bbl. In the cyclic rich gas the ultimate recovery is estimated to be 3.3MCF/bbl. With no significant increase in operating cost, the primary cost of the process was in the investment in gas supply and injection.

These additional tests show that in a light oil pressure- depleted resefl'oir with natural fracturing. cyclic rich gas and cyclic nitrogen/carbon dioxide mix can yield excellent recovery efficiencies, and can be more efficient than cyclic carbon dioxide,

P. 501
A New Way of Optimising Contract Management and Co-operation Between Operator and Service Company
Authors: Torsvoll A. , Grotmaol O.
Published: December 2007

This is a summary of the added value obtained in a Joint Business Development (JBD) between an operator and a service company. The business development is founded in a Joint Operations Agreement formalised and signed by both parties early 1996.

This business development is unique because of its structure, and its systematic approach to jointly improve quality, communication, developing technology to meet needs, and the resulting added value to both parties.

This project was started in 1994 with a restructure of operators contract portfolio. The goal was to achieve improved cost efficiency, closer co-operation with suppliers and to reduce overall contract administration.

This was to be achieved by reducing overall number of contractors, combined with, transferring increased responsibility to the service company.

This system together with other Non Conformity and Health, Safety And Environment systems are used by both parties to focus on quality, and optimise resource use.

A system to identify gaps in behaviour, communication and expectations was also put in place.

Once the measuring systems were operational, a initiative was taken to do a large scale co-operative survey, focused on both technological and co-operational improvement opportunities. The result of the survey was then used to establish project specific Quality Action Teams with representation from both parties.

This way of working together has resulted in demonstrated improvements, that has given added value to the parties in several critical areas.

The process is under continuos development, and based on experience to date, the parties are preparing to take appropriate elements of the Joint Business Development process to the international arena.

P. 589
Production Management of Electric Submersible Pumps Using Expert System Technology
Authors: McLean Dan , Clay Roger , Gould Wayne
Published: December 2007

Management of electric submersible pumps (ESP) at wellsites can be improved using expert system technology to combine real time sensor information with production engineering knowledge rules. When abnormal conditions exist on an ESP well it is not always apparent that there is a problem until significant production loss and/or the results of pump damage become apparent. By applying expert system technology and elements of artificial intelligence, visualization of well performance in relation to the pump manufacturer's operating limits can be presented to operations personnel in real time. The well performance can then be maximized once the operating constraints are known and algorithms to optimize production can logically follow. The expert application described in this paper demonstrates this ability and can be extended easily to multiple well sites. The application was written for production at ARCO Alaska's West Sak field in parallel with the field development. The primary objective is to reduce operating and maintenance Costs by providing virtual operations assistance so that new wells can be operated and optimized using existing operations personnel.

P. 617
Calcite Scaling Tendencies for North Sea HTHP Wells: Prediction, Authentication and Application
Authors: Jasinski Raymond , Fletcher Philip , Taylor Kate , Sablerolle Willem
Published: December 2007

Calcite scale is generally encountered during hydrocarbon production in the North Sea. The optimization of completion design for both inhibition and remediation requires accurate forecasting of when a treatment will be required and how much treatment will be necessary. In this paper application of four water chemistry simulators to these objectives will be described for two HTHP waters, and two fields operating under less stringent environmental conditions. It will be shown that computer simulation of this scale formation chemistry becomes increasingly difficult for formation waters with temperatures above 250F and 6000 psi. We also describe the technology involved in designing a rigorous simulation model capable of simulating calcite scaling under these HTHP conditions, as well as validation of the model predictions vs. laboratory and field data.

P. 661
An Interactive Drilling Dynamics Simulator for Drilling Optimization and Training
Authors: Dubinsky V.S. , Baecker D.R.
Published: December 2007

The dynamic behavior of the drill bit is a critical factor in drilling efficiency. It affects ROP, hole conditions and the frequency of bit trips. Improved understanding of this behavior can result is significant improvements in all of these areas.

For this reason an interactive PC-based simulator has been developed. This system simulates the dynamic behavior of the drill bit for various drilling conditions. These conditions are defined by numerous downhole and surface factors, such as hook load, RPM, mud properties and flow rate, BHA configuration, drill bit design, borehole parameters, and formation properties. This system allows for accurate simulation of the major drilling dynamic dysfunctions, such as bit bounce, lateral vibrations, BHA / bit whirl, torque shocks, stick-slip and torsional oscillation.

The system was developed using field test results and both theoretical and practical knowledge about dynamic behavior of the drillstring, BHA and drill bit under certain drilling conditions. The so-called "System Identification" approach has been used as a basic tool for creating the simulator's internal model. The downhole dynamic and static measurements required for developing such a model were recorded at a high sampling rate during the field test of a prototype of an MWD downhole dynamics tool.

The simulator has certain self-learning capabilities and its "smartness" depends upon the amount of data used for developing and training the model. The simulator could be used as a key element in a closed loop drilling system which would allow the driller to be more reactive to any undesirable change in downhole dynamic conditions. By using the simulator "on-line", one could play different scenarios (i.e., drilling ahead based on the existing or anticipated drilling conditions). This could improve the selection of drilling parameters from the surface prior to event occurrence. Therefore, ROP could be optimized while reducing the severity of downhole dynamic dysfunctions. The simulator could also be efficiently used as a training tool for MWD operators and drilling personnel.

P. 639
Non-Darcy Flow Experiments in Anisotropic Porous Media
Authors: Cooper J. , Wang X. , Mohanty K.K.
Published: December 2007

The velocity-pressure drop relationship in the near-wellbore region of high capacity gas and condensate reservoirs often deviates from Darcy's law. Furthermore, many naturally occurring porous media are anisotropic and often layered. This study is directed at combining these facts in developing a mechanistic understanding of non-Darcy gas flow in anisotropic porous media. Non-Darcy flow coefficients, permeabilities, and electrical tortuosities are measured in cores with layers both in the parallel and perpendicular directions to flow and in non-layered, anisotropic cores. The presence of a connate water saturation decreases permeability in all cores but increases the non-Darcy coefficient significantly only in the perpendicular core. Both a macroscopic and a pore-scale network (microscopic) model of anisotropy are proposed. The product of permeability and non-Darcy coefficient is shown to be less anisotropic than either the permeability or the nonDarcy coefficient tensors in both experiments and simulations. In the microscopic model, the non-Darcy term has been found to be tensorial and proportional to the square of the superficial velocity at the macroscopic scale. As the pore-scale anisotropic parameter increases, non-Darcy coefficient and tortuosity increases, but permeability decreases. The models developed show order of magnitude agreement with experimental data.

P. 609
Discriminating Fracture Patterns in Fractured Reservoirs by Pressure Transient Tests
Authors: Wei Lingli , Hadwin Jerry , Chaput Eric , Rawnsley Keith , Swaby Peter
Published: December 2007

A new approach is described to characterise fractured reservoirs using a software code which can simulate transient well tests in a realistic 3D fracture/matrix model. By a process of iteration the geological and flow data can be reconciled to produce plausible models which could help to constrain reservoir simulation. The numerical results indicate that the simulated pressure derivatives generally show different characteristics with different fracture pattern configurations. The results also indicate that theoretical dual porosity behaviour is absent when a more realistic transient matrix to fracture flow solution is used. This approach has important implications in the use of well tests to determine parameters for input to a multiphase flow simulator, where the well positioning in relation to highly conductive fractures is critical. The advantage of the described approach, compared to conventional analytical analysis. is that the geological data are calibrated and preserved. Parameters can then be more accurately represented in a dynamic reservoir model.

P. 609
Estimation of Permeability Anisotropy and Stress Anisotropy From Interference Testing
Authors: Chen Her-Yuan , Hidayati Dewi Triarti , Teufel Lawrence W.
Published: December 2007

The purpose of this study is to relate current multi-well testing technology, which is limited to the estimation of fluid flow/storage properties, to the flow-induced stress changes of an anisotropic reservoir. Results suggest that the evolution of reservoir stress anisotropy will be influenced by the trend of permeability/flow anisotropy. A simple and reliable method is further developed to identify the trend of permeability/stress-change anisotropy using interference testing data. Examples based on published field data are given to show the main concept.
An Integrated Study of Reservoir Compartmentalization at Ewing Bank 873, Offshore Gulf of Mexico
Authors: Edman J.D. , Burk M.K.
Published: December 2007

Ewing Bank 873 is an offshore Gulf of Mexico field discovered in 1991 in 775 ft of water. The discovery well was drilled on a seismic amplitude anomaly on the flank of a salt withdrawal mini-basin. Field development began in 1994, and in mid 1998 daily production from the Bulminella 1 reservoir averaged 40,000 BOPD and 32 × 106 ft3/D of gas. The Bul 1 reservoir in this combination structural-stratigraphic trap consists of six stacked and overlapping Pliocene turbidite sand lobes. In turn, integration of seismic, well log, geochemical and pressure data indicates these six turbidite lobes comprise three compartments. All of the various data types give constraints on different aspects of compartmentalization, but at the stratigraphically complex Ewing Bank 873 field, geochemical analyses provided key information unavailable through any other means. These geochemical analyses were performed as individual wells in the field went on production and immediately provided information regarding fluid communication and reservoir connectivity that was missing from earlier interpretations based solely on seismic and log data. Early recognition of three reservoir compartments using geochemical data also helped constrain preliminary stratigraphic interpretations and provided initial input for flow units and reservoir simulation models. The geochemical information further provided advance notice of economically significant oil quality variations in the three compartments. These fluid variabilities were later substantiated by PVT analyses and include notable differences in oil gravity, weight percent sulfur, viscosity and solution gas. Integrating all available data shows there are three compartments at EW 873 and each compartment comprises different turbidite sand lobes and exhibits its own characteristic pressure regime and fluid properties. The early indications of both compartmentalization and variation in fluid properties by the geochemical analyses contributed significantly to improved field recovery and economics by allowing fewer and better placed wells to be drilled.

P. 653
Development Drilling of the Tawila Field, Yemen, Based on Three-Dimensional Reservoir Modeling and Simulation
Authors: Beattie C. I. , Mills B. R. , Mayo V. A.
Published: December 2007

Canadian Petroleum Ltd. and partners in the Yemen Masila Block have successfully used detailed three-dimensional reservoir modeling and reservoir simulation to optimize the development of the larger oilfields in the Masila area. The models were used to predict reservoir performance and plan additional development drilling which subsequently demonstrated that the models accurately predicted drilling results.

The main producing horizon in the Masila area is the Cretaceous Upper Qishn formation, a clastic-dominated transgressive depositional sequence with fluvial sediments at the base, tidal dominated estuarine sediments in the middle, and marine shoals at the top. This variable array of facies presents modeling challenges but the resulting heterogeneous models provide a realistic representation of actual reservoir characteristics. This paper describes the approach used to stochastically distribute both facies bodies and petrophysical parameters, and to upscale the model for reservoir simulation, while preserving the complex reservoir description.

The Tawila field was the first Masila field to have wells drilled on the basis of the modeling effort, with very encouraging results. For these new well locations, the model successfully predicted both reservoir development and oil-water contact movements resulting from production from existing wells. This paper presents key conclusions and predictions from the modeling and reservoir simulation, and compares them to the results from subsequent drilling. As a result of the successful development drilling, these models are now an integral part of reservoir management and development planning for all Masila fields.
A Quick Method of Identifying and History Matching A Gravity Dominated Reservoir with Localized Super-Permeabilities
Authors: Al-Dhamen A.A. , Pham T.R. , Al-Khatib M.A.
Published: December 2007

This paper discusses a quick method of identifying and history matching gravity dominated reservoir area with localized Super-permeabilities (Super-K). The area of interest is part of a large elongated carbonate antic line Middle-East oil reservoir. Wells in the area of reservoir of interest are prolific producers with a high degree of Super-K occurrences. Layers with Super-K usually contribute more than half of the flow from few feet interval. Figure-l is a flowmeter which indicates a flow contribution of more than 50% from a dolomitic Super-K layer.

The lack of geological data and wide well spacing offers little help in identifying the areal extents of these Super- K layers. Therefore, correctly history matching the reservoir may be difficult due to the non-uniqueness nature of reservoir modeling that the match may be achieved with a wide variety of reservoir descriptions and permeability arrays. However, if the reservoir fluid mechanic could be identified, then the history match may be facilitated. The paper will discuss:a quick procedure of identifying whether the Super-K are localized or are a really widespread by using the simulation model in conjunction with flowmeters and production data.A quick procedure for pressure and saturation match.

These procedures are practical and help identify the reservoir fluid mechanics at the beginning phase of history matching.

In the case of the reservoir of interest, the model helps prove that most of the reservoir is gravity dominated even with a high degree of Super-K occurrences. The paper will outline how the well test permeability thickness data and the flowmeters are employed in constructing the model. It will discuss a quick, systematic procedure of pressure and saturation match. The overall match was achieved in a short time of a model with approximately 100 wells. The discussion will highlight the fact the knowledge of reservoir fluid mechanic and its behaviour is important before any attempt of history match is made.

P. 753
Oil Recovery from Bottom Beds of Kuwait Oil Lakes by Retorting
Authors: Elgibaly Ahmed A.M.
Published: December 2007

During the Gulf War in 1991, over six hundred oil wells were blazed in Kuwait. Oil gushed from these wells and resulted in the formation of more than 300 oil lakes covering an area of about 49 km2. According to recent studies the amount of the heavily contaminated bottom beds of these oil lakes has been estimated as 40 to 50 million tons. Oil extraction from these beds is necessary to reduce their environmental nuisance. Various methods were proposed for this purpose, but to date none has been accepted for application on large scale. This study investigates the potential of retorting as one of the most promising methods.

Experiments were performed on samples from different oil-lake sands heated to 500-600 C. The quantity and quality of oil produced and the reaction rate within the porous material have been studied. The effects of heating rate, operating pressure, water content, and specific surface area of the bed matrix were investigated. Four successive pyrolysis stages were observed during the retorting process: water volatilization, oil volatilization, vis breaking, and coking. A mathematical model was developed to describe the pyrolysis kinetics of the oil sand samples. The model was based on material balance, which involved kinetic expressions for reaction rates of the various mechanisms. Based on the experimental data, the developed model predictions agreed reasonably well as compared with the available models. The fluid holdup and coke, deposited within the porous medium, were also predicted during the retorting process. It was found that volatilization/distillation and vis breaking were the most dominant mechanisms that contributed considerably well in oil recovery. A simple model was also proposed to describe the kinetics of crude oil vis breaking within the oil- contaminated sand sample during retorting process. The model fitted well the experimental data.

P. 809
The Effect of Wettability on Three-Phase Relative Permeability
Authors: DiCarlo David A. , Sahni Akshay , Blunt Martin J.
Published: December 2007

We study three-phase flow in water-wet, oil-wet, and fractionally-wet sandpacks. We use CT scanning to measure directly the oil and water relative permeabilites for three-phase gravity drainage. In an analogue experiment, we measure pressure gradients in the gas phase to determine the gas relative permeability. Thus we find all three relative permeabilities as a function of saturation. We find that the gas relative permeability is approximately twice as high in a water-wet system than in an oil-wet system at the same gas saturation. The water relative permeability in the water-wet pack and the oil relative permeability in the oil-wet pack are similar. In the water-wet medium the oil relative permeability scales as kr0 S04 for So >Sor~ where Sor is the waterflood residual oil saturation. With octane as the oil phase, kro So2 for So < Sor~ while with decane as the oil phase, kro falls sharply for So < Sor. The water relative permeability in the oil-wet medium resembles the oil relative permeability in the water-wet medium for a non-spreading oil such as decane. These observations can be explained in terms of wetting, spreading, and the pore scale configurations of fluid.

P. 869
Wettability Change Related to the Adsorption of Organic Acids on Calcite: Experimental and Ab Initio Computational Studies
Authors: Legens C. , Toulhoat H. , Cuiec L. , Villieras F. , Palermo T.
Published: December 2007

We have investigated the interactions between organic acids and a calcite powder by adsorption from an organic phase (benzoic acid and lauric acid in toluene) and from an aqueous phase (benzoic acid and lauric sodium salt.

In addition to the experimental study, ab initio quantum chemistry calculations were performed for cluster models, simulating the interactions of molecules with calcite surface sites.

At the toluene/calcite interface, acids chemisorb on surface calcium ions, replacing surface hydroxyls resulting from the previous surface hydration by water. This surface saponification phenomenon was predicted by ab initio calculations and confirmed by spectroscopic techniques. The adsorbed acids conferred a hydrophobic character to calcite, with the higher contact angles in water for the longest alkyl chains in the organic acid.

At the water/calcite interface, organic acids do not displace water.

As electrostatic forces determine the stability of thin water films between calcite and crude oils at reservoir conditions, from our calculations, we deduce that when crude oil fills the biggest pores of the reservoir rock, oil/calcite interfaces appear where the adsorption of organic acids can change the wettability to oil-wet. By contrast, the mineral should remain water-wet at places where the capillary pressure has not been able to thin the aqueous phase beyond a critical value at which the film would collapse. This can occur even if the aqueous phase contains dissolved organic acids transferred from crude oil. Mixed wettability patterns might therefore be related to the spatial distribution of pore sizes.

Our results support the latter conclusion in the specific case of organic acids with calcite.

P. 889
A Validation Criterion for Optimum Petrophysical Characterization of Reservoir Zones
Authors: Worthington P.F.
Published: December 2007

This paper was prepared for presentation at the 1998 SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, 27-30 September 1998.
Integrated Study of a Faulted and Fractured Reservoir
Authors: Lyon T. A. , Fuller J. , Granier B. , Hozayen M. , Al Riyami A. , Khalaf A. , Thiebot B.
Published: December 2007

This paper presents a case study drawn from an integrated reservoir study on a faulted and fractured carbonate reservoir offshore Abu Dhabi. Particular emphasis is put on demonstrating how the results of 3D seismic interpretation impacted the structural understanding. The paper also explains how the seismic interpretation, well-bore observations and production data were integrated to provide an improved reservoir model.
Development of a Bottom-hole Energy Source for Active-SWD
Authors: Yokota Toshiyuki , Mizohata Shigeharu , Kozawa Takeshi , Shimada Nobusuke , Tsuru Tetsuro , Taniguchi Ryosuke
Published: December 2007

"Active-SWD (Seismic While Drilling)" is a newly proposed data acquisition method which utilizes an artificial source in addition to the seismic wave generated by the rotating drill-bit. With this improvement, Active-SWD can acquire higher quality data when drilling soft formations with a PDC bit than conventional SWD data acquisition which uses only the drill-bit as a seismic source.

Based on the Active-SWD concept, this paper describes our first and second generation bottom-hole sources which employ an electric magnetostrictive hammer (EMH) developed by Japan National Oil Corporation (JNOC) and Mitsubishi electric corporation.

The objective of the first generation bottom-hole source was to increase its output energy by implementing the resonance of a spring-weight system. The principal shortcoming of this source was that, its source-signature frequency spectrum was highly monochromatic and required sophisticated software to recognize the first break times. A pattern recognition technique was designed for first break picking which gave good results for synthetic data situations. However, further development was needed for application to field data circumstances.

The second generation, bottom-hole source has a broader source frequency spectrum and an increase in total energy output. This increase results from combining the emitted signals from the drill-bit and the artificial source. Conventional SWD processing techniques can be used for processing data generated by this new source.
A Guideline for Research in Affluent Developing Countries
Authors: Sevgur S. B. , Islam M. R.
Published: December 2007

Research is considered to be something elite and is often related to predominantly graduate schools. Recently, there is a push in the United States toward putting the burden of research on individual faculty members, arguing that university should exist with the sole purpose of teaching and any research should be done at the professor's own time. It is even suggested that any extra incentive of doing research during the academic year be eliminated and professor focus on nothing but teaching during the academic year (Bess, J. Higher Education: 69(1), 1998). This short-sighted view can be attractive for many who are interested in making a university professor's life more miserable than it already is, but in-depth look will reveal that this policy is guaranteed to make a university less than third-class in ranking. If one understands the meaning of research and higher education, one can clearly see that research is not luxury, it is rather a necessity for even the most modest of undergraduate institutions. Particularly in engineering education, the need of research is often misunderstood while the need of fancy equipment is glorified. An engineering educator should instead focus on productivity, collaborative research and its inherent relationship with creative thinking and innovation. Most universities in developing affluent countries are indeed predominantly undergraduate institutions and can fall in the trap of non-research, based on the fallacy that research belongs to graduate institutions. Administrators, who often do not rationalize from the perspective of faculty members, have crucial role to play. It is a matter of deciding to make the university strong both in research and teaching or let the university slide into a pitfall of a merely mediocre government institution. Both are possibilities, and the probability of one of them being the option is not trivial.

This paper details the need of research and provides one with a guideline suitable for a seemingly prosperous yet developing country, such as the United Arab Emirates. In this context the recent developments in the western countries are discussed and compared vis a vis efforts in the developing countries.
High Rate Gas Well Design: Issues and Solutions - Goodwyn Gas Condensate, NWS, Australia
Authors: Teng D. , Nettleship G. , Hicking S. , Hindmarsh K.
Published: December 2007

Goodwyn platform wells produce up to 220MMscf/d of raw gas yielding up to 20,000 bpd of stabilised condensate. The high productivity of the wells has reduced the number of development wells needed to satisfy platform capacity with significant cost savings. This high well capacity was achieved through the early recognition of the reservoir inflow potential in the completion design and addressing the critical issues of erosional velocity, lifecycle sand production, sub-surface and surface equipment integrity in a high flow, high stress environment. To maximise the well potential the erosional limit was extended based upon actual experience. The risk of sand production was managed through a philosophy covering sand prediction and its control during operation. Well hardware was tightly specified and qualified within the defined operating envelope. These solutions were applied to both the initial conventional wells and for the later extended reach horizontal wells. Results from Goodwyn wells demonstrate that actual performance match the targeted ideal and that the issues have been manageed.

This paper presents a systems approach to well design where technical and external issues are taken into consideration. It is a retrospective look at the issues addressed for Goodwyn well design, with updates to include current techniques.

P. 281
Evaluating the Transport of Solids Generated by Shale Instabilities in ERW Drilling
Authors: Martins A. L. , Santana M. , Gaspari E. , Campos W.
Published: December 2007

The problem of cuttings transport in the inclined sections of ERW's is a major concern in the oil well drilling industry. This paper presents an innovative time dependent mathematical model, along with a computer implementation of it, which is based on the well-known two-layer model approach. An innovative feature of this model consists in the consideration of the added amount of solids that comes from the crumbling and cave-in of the well bore. The unstable effects of this added amount of solids is taken into account through a variable representing the added volume of cuttings per unit time and length. A finite volume approach is used to solve the system of differential equations. The paper represents a first step on the integrated analysis of cuttings transport and well bore stability problems.
Modeling Multi-Lateral Wells
Authors: Su Ho-Jeen , Fong William S.
Published: December 2007

A computation scheme was implemented in a general-purpose, finite-difference simulator to model multi-lateral wells. Frictional pressure drop along the wellbore and proper fluid mixing at lateral connection points were included in the calculation of wellbore pressure profile for each lateral. The formulation is general and a lateral can be branched out from any point along the main well path.

Since the production profile of each lateral is influenced by the wellbore pressure distribution, the prediction accuracy depends on a good wellbore flow model. We implemented the Beggs and Brill1 correlation, a homogeneous flow model, and a new model proposed by Ouyang et al2 which included an acceleration term and accounted for the lubrication effect due to radial influx. We compared well performance prediction results using the three models.

We studied the impacts of different tubing sizes on the well performance and the production contribution from each lateral.
Investigation of SAGD Steam Trap Control in Two and Three Dimensions
Authors: Edmunds Neil R.
Published: December 2007

Steam trap production control, i.e. producing fluids to maintain BHT just below the boiling point of water, has been traditionally recommended for SAGD operations. In this work a numerical investigation of the relationships between producing steam trap subcool setting and related parameters of interest such as fluid level, pressure, production rate, and steam/oil ratio is reported for a prototype Athabasca reservoir.

It is found that steam trap dynamics are rather more complex than previously imagined. In three dimensions and the real world, for example, inflow temperature can and does vary significantly along the well according to local conditions, resulting in 3D simulations predicting significantly lower production rates than equivalent 2D cases. The findings have implications to many aspects of SAGD engineering including process optimization, forecasting, completion design and installation, production operations and performance analysis.
The Successful Use of Transverse Hydraulic Fractures from Horizontal Wellbores
Authors: Crosby D. G. , Yang Z. , Rahman S. S.
Published: December 2007

Multi-stage, transversely fractured horizontal wellbores have the potential to greatly increase production from low permeability formations. Such completions are, however, susceptible to problems associated with near-wellbore tortuosity, particularly multiple fracturing from the same perforated interval. A criterion, based on that by Drucker and Prager, has been derived, which predicts the wellbore pressures required to initiate secondary multiple transverse hydraulic fractures in close proximity to primary fractures. Secondary fracture initiation pressures predicted by this new criterion compare reasonably well with those measured during a series of unique laboratory-scale multiple hydraulic fracture interaction tests. Both the multiple fracture initiation criterion and the laboratory results suggest that close proximity of primary hydraulic fractures increases the initiation pressures of secondary multiple fractures by the order of only 14 percent. This demonstrates that transversely fractured horizontal wellbores have limited capacities to resist the initiation of multiple fractures from adjacent perforations or intersecting heterogeneities. Petroleum engineers can use the multiple fracture initiation criterion when designing hydraulic fracture treatments to establish injection pressure limits, above which additional multiple fractures will initiate and propagate from the wellbore.
Systematic Approach Enhances Drilling Optimization and PDC Bit Performance in North Slope ERD Program
Authors: Wolfson Larry , Mensa-Wilmot Graham , Coolidge Robert
Published: December 2007

Technological advancements have enhanced operational efficiency in North Slope directional and horizontal drilling applications. These gains result from resolution of technical and economic issues that once seemed insurmountable in extended reach drilling programs. Well profiles have become more challenging because of our need to reach targets, depths and departures that previously seemed unrealistic. Regardless of our current levels of success, there is the urgency to develop methods and processes that will further improve drilling efficiency. As such, it is imperative that a systematic, logical and quantifiable approach for developing and implementing technologies in these types of applications, especially Extended Reach Drilling (ERD) programs be defined.

This paper will show how this approach was used to enhance drilling efficiency in the intermediate section (12-1/4" hole size) of a North Slope ERD program. It defines and quantifies two sets of parameters for the drilling operation: performance objectives and requirements on a "per interval" basis. It evaluates the functional relationships and dependencies among the drilling operation's components. Although effective in directional, horizontal and ERD applications, the method promotes continuous improvement and makes it useful in any drilling environment.
Gannet E Subsea ESP: The Application of Technology in Practice
Authors: Harrall S. J. , Nevelsteen D.
Published: December 2007

The Gannet E single well subsea ESP development has been on stream since January 1998. This is the first such installation in the North Sea, and is only the third development of its kind in the world. At a 14km step-out from the Gannet Alpha platform, Gannet E represents a world record in terms of electrical transmission distance for such developments. Since start-up, flowrates of 18,000 barrels of oil per day have been sustained, whilst valuable operating experience has been acquired in a relatively short time span. During the project planning and execution phases, emphasis was placed upon anticipating potential operational pitfalls which could jeopardize the overall success of the development. Areas of concern lay in the fields of: ESP control and run-life;Control of the platform facilities;Electrical power transmission;Data gathering;ESP flexibility with respect to flowrates and required delivery pressures;Reservoir-related uncertainties;Well completion installation.

The paper describes the technology and techniques applied in order to Maximise the safeguards to the overall system integrity and deliver a robust development. Actual start-up and running experience is discussed in relation to the planning effort. Attention is paid towards the analysis of trips and the evaluation of operability limits over the whole system. The major learning points which are being carried into further projects of this nature are also presented.
Massive Fracture Stimulation in Deep, High-Pressure Athel Formation
Authors: Wong Sau-Wai , Ford Steve , Turner Bob
Published: December 2007

The deep, high pressure Athel reservoirs are located in the South Oman Salt Basin. Due to low permeability, un- stimulated well rates are low. Recently, two wells have been stimulated with the largest hydraulic fractures in the Middle East. The post-frac production lives up to expectation. The well design and stimulation approach has significantly improved the economic viability of the Athel accumulation.

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Neural Net Identification of Flow Regime using Band Spectra of Flow Generated Sound
Authors: van der Spek Alex , Thomas Alix
Published: December 2007

Multiphase production log interpretation requires that the flow regime along hole in the wellbore is known. Flow regime is the cased-hole analogue of lithology. Knowledge of the flow regime will help to interpret tool signals, will help to evaluate the flow rate on a per phase basis, and will reduce post processing load by at least a factor of 10. Flow regime can be classified correctly by a neural net in up to 87% of all cases using 1/3 octave band spectra of flow generated sound. A neural net trained on commercially available tool data (noise cut's) appears to be too sensitive to the wellbore inclination. Hence, application of automated neural net interpretation of noise logs requires a new generation of noise logging tools.

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A New Low Risk Technique of Forming A Level 6 (TAML) Multilateral Junction
Authors: Hogg William Clifford , MacKenzie Alan
Published: December 2007

Within the last two years, multilateral systems offering full hydraulic and mechanical integrity have become commercially available in the petroleum industry. Emphasis has now begun to shift toward increasing the flexibility of these systems while minimizing the overall risk associated with the implementation of the multilateral. This paper details the development of a new Level 6 (TAML) type of multilateral that offers mechanical and hydraulic integrity and allows full liner bore access into either lateral, as demanded by the industry. Descriptions of the system and its development are discussed along with an assessment of the risk minimization possible with this new type of multilateral as compared to current state-of-the-art multilateral systems.

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North Sea Harding Project: A Well Engineering Case History Success
Authors: McLellan W. , Ferguson M. , McKay G. , Hough S.
Published: December 2007

This paper discusses the Well Engineering successes of BP's current North Sea Harding Project and the intrinsic reasons behind them, with particular reference to the management philosophies and engineering technologies utilised to ensure maximum performance, productivity and efficiency. The key contributory areas are discussed in both overview and detail format as appropriate.

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Cuttings Flow Meters Monitor Hole Cleaning in Extended Reach Wells
Authors: Naegel M. , Pradie E. , Delahaye T. , Mabile C. , Roussiaux G.
Published: December 2007

This paper presents an innovative solution to monitor hole cleaning in Extended Reach Wells. It was successfully used while developing marginal oil and gas reserves offshore TIERRA DEL FUEGO (ARGENTINA) by TOTAL AUSTRAL operator and partners DEMINEX and PAN AMERICAN ENERGY.

Keeping the hole clean in Extended Reach Wells is a key issue as cuttings accumulation will result in increased torque, pressure losses and will create a high risk of getting a stuck pipe.

Cuttings Flow Meters (CFM) continually measure and record the flow of cuttings at the outlet of the shale shakers. This measurement allows an enhanced understanding of hole cleaning process and status, which in turn permits to optimize the main drilling parameters such as flow rate, rotation, circulation times, reaming time at connections and rate of penetration.

It has been observed on those wells that the volume of cutting returns always fits with the actual volume of hole, over extended periods of time. By comparing on a permanent basis the volume of hole drilled with the volume of cuttings returned to surface, one can monitor the cuttings accumulation in the hole, one can thus better diagnose an increase in hole friction, adjust mud rheology parameters and circulating rate in order to minimize the surface and bottom hole circulating pressures while ensuring a good transport, all factors which are essential to further extend the drilling envelope.

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Breakthrough Well Suspension Operations in West of Shetland Horizontal Wells
Authors: Elliot G. , Makin G.D. , Ferguson S.E. , Moyes P.B.
Published: December 2007

Foinaven is the first field to be developed in the deep water, West of Shetland. A sub-sea development, in 500 metres of water, Foinaven will have fourteen production wells. Most of these wells will have extended reach horizontal sections, completed with sand control screens. The challenging weather conditions mean that a number of the wells are suspended once the screens are in place, with the upper completions being run when the weather is less severe.

The suspension operations required plugs to be set using drill pipe or coiled tubing, from a semi-submersible rig capable of operating in the West of Shetland environment. The high day rates associated with these vessels mean that a major cost saving can be realised by eliminating these interventions.

This paper describes the planning, development, and field deployment of a deep-well barrier system which is installed as part of the sand control completion. The clear understanding of the well objectives led to the creation of a system whose benefits exceeded simply reducing the cost of the completion operations, namely:–deep well suspension without well intervention;–protection against fluid losses immediately after completing the reservoir section;–improved well productivity;–less operational risk during the completion phase;–reduced personnel exposure to harm due to less rig-up operations;–shorter well clean-up times;–ability to run the completions underbalance.

At the time of writing this abstract, four Foinaven wells have been completed in this fashion. The learning from these first applications has led to such systems gaining increasing acceptance throughout the industry.

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