bluuebunny/crossref_metadata_2025_split huggingface dataset:
Role and Contribution of Pressure Regime Evaluation in Well Planning and Formation Evaluation Process, Zeit Bay Field - Gulf of Suez, Egypt
Authors: Selim Saber Moustafa , Badawy Bassem El-Sayed , Abdullah Khaled Mohamed , Khorshid Mohamed Ayman 
Published: October 2008

Summary:
The study aims to construct a simple and effective pressure regime model for Zeit Bay Field which can assist the well planner to predict the pore pressure for the upcoming wells to be drill in the field. It aims also to find out the relationship between the constructed pressure regime model and the geological setting of the field.

Introduction:
An adequate prediction of the Pore Pressure and better understanding for the Pressure Regime Model of any area are very important prior drilling any well. They can play a vital role at several stages of Exploration and Development Process. ? In Exploration Phase, they help in:-Providing calibration to Basin Modeling.Mapping Hydrocarbon Migration Pathways.Assessing the "Seal" effectiveness.Analyzing the "Trap" configuration and geometry for a Prospective Basin. In Development Phase, they help in:-Anticipating the location and potential magnitude of possible formation pressure problems.Providing suitable casing and mud program designs leading to Minimize Drilling Cost.Avoiding Environmental Pollution, Loss of Reserve, Loss of Human Life...etc). But it is worth mentioning that, it is very important to recognize and evaluate any changes in the Estimated Pore Pressure data during the drilling of a new well. The updated information can be used to implement the new well proposal.

General Outline about Zeit Bay Field:
Zeit Bay field is an oil field located in the southwestern offshore part of the Gulf of Suez, some 65 km north of Hurghada and 85 km south of Ras Gharib. The field extends to the onshore and is combined with General Petroleum Company's Bahar North -East field. (fig.1)
The field was discovered in June 1981 through the drilling of the Exploratory well "QQ 89-1" which was drilled in the crestal part of the structure and considered as gas producer well. In October, 1981 another well "QQ 89-2" was drilled 2 km south and down dip from well QQ 89-1. This well recorded the underlying oil-leg with an oil water contact at 4850 feet sub-sea.
The commercial field production has been started in December 1983 with average daily rate 20000 BOPD.
Structurally, Zeit Bay field is interpreted as a NW-SEbasement relief like anticline feature. This anticlinal feature is however, dissected into several fault block panels by two main fault systems. A set of NW-SE trending faults affecting the western and eastern flanks. Another set of W-NW/E-SE trending fault system affecting the northeast flank. Some of these faults die out at/ or near top Belayim except the extreme bounding faults. In addition to the northeast and southwest blocks there are a parallel narrow elongated rectangular high blocks down stepping away from the above triangular horst blocks. (fig.2)
How Water Depth Affects Extended Reach Drilling
Authors: Rocha Luiz Alberto S. , Andrade Renata , Soffried Klaus 
Published: October 2008

Abstract
Over the last years, the drilling of extended reach wells (ERW) has become almost common practice in the oil industry. Although it still poses many technical challenges, successful applications such as the ones at Witch Farm, UK or in the South China Sea spurred the interest in ERW by the operators. In parallel, with the push for even further lateral displacement of wells, another technology frontier emerged for drillers: Extended reach wells in deepwater.
The majority of the extended reach wells are drilled from onshore sites to reservoirs that are situated under sensible locations like preserved nature or urbanized areas. Extended reach wells drilled from fixed platform installations in shallow water usually are aimed to reach outer parts of reservoirs that otherwise could not be developed economically. In deepwater, ERW allows the use of dry completion platforms such as TLP or SPAR. It improves flow assurance and reduces the cost of the well and the future interventions.
The paper at hand gives an overview on the effects of water depth on extended reach drilling (ERD) and has been divided in two sections. The first section is aimed to provide a general overview and examine the direct impact of water depth and pressure gradients on great displacement wells. It presents a number of ideas and practices currently used by operators. It also discusses applied solutions obtained from the associated literature and from interviews with experts in several service companies. Among others, new technology related to hole cleaning, torque and drag reduction and ECD management are discussed.
The second section of this paper will look at possible solutions to the engineering challenges based on analytical methods. Tools such as rotary steerable technology, LWD, high torque drillpipe, non-rotating stabilizers and drillpipe protectors, hydraulic by pass subs and others are analyzed as part of an integrated planning approach. Several effects that different water depths scenarios have on ECD, torque, drag and formation pressure gradients are simulated, and discussed.

Introduction
It is common to think about ERW as directional wells that have the displacements much higher than the total vertical depth (TVD). It is also acceptable to use the ratio between horizontal displacement and TVD (DTVD) to classify directional wells. According to this relation, wells could be classified as follows
1500 hp AC Drive Motor Design for Oil Field Drilling Operations
Authors: Al Akayshee Qasim , Williams Kevin 
Published: October 2008

Abstract
The paper describes the design and testing of an induction motor. The design for this machine, which is to produce 1500 hp continuously, was first calculated using a conventional equivalent circuit with analytically derived parameters. 2D finite element analysis was then used to obtain an optimum result. A thermal lumped circuit program was also employed to predict the temperature of the winding. Experimental results are given to validate the work.

Introduction
The AC drive system has been designed to meet the rugged demands of marine and drilling applications, the system replaces an earlier DC machine drive and employs the OEMV3000 [1] - Active Energy Management Drive to give virtually zero harmonic distortion of supply current and unity power factor.
Many things can affect the smooth running of a process and produce adverse process conditions. In the past, the self-protection philosophy of variable speed drives resulted in drive tripping or shutting down. The level of intelligence and protection in the OEMV3000 means that these self-protecting trips are no longer necessary. This new drive system (Fig. 1.) can take intelligent action in the event of adverse process conditions, resulting in higher plant availability and warning of process problems before they occur.

Motor Construction
The machine has 6 poles. The double layer 10/12 corded stator winding is accommodated in 72 slots. The stator laminations are made from Losil material. Class H inverter grade wire is used so as to withstand the sharp impulse repetitive waveforms produced from the switching process at high frequencies. The rotor has 84 slots and carries copper bars.
Fig. 1 The AC drive system(AVAIALBLE IN FULL PAPER)

Design Strategy.
This depends on the iteration between the electromagnetic equivalent circuit algorithm and the lumped circuit thermal design algorithm. These two packages are based on analytical methods and enable many design ideas to be examined in a short period of time. The aim is to try to optimise the overall design. The electromagnetic and thermal designs need to be considered at the same time because they are interdependent; the losses being dependent upon the temperature and the temperature on the losses.
Electromagnetic finite element analysis is used to fine-tune the design. It enables the precise flux distribution and saturation levels to be determined and improves the accuracy of the predicted performance. A photograph of this new motor is shown in Fig.2.
Otter: The World's Longest Subsea Tie-Back With Dual ESP
Authors: Horn Mark , Coudeville Frederic , Bespalov Eugene , Butcher Howard 
Published: October 2008

Abstract
The Otter field in the Northern North Sea has been developed using three subsea production wells each equipped with dual electric submersible pumps (ESP). Dual ESP were selected as they will maximise well availability and minimise operating costs associated with workovers. The field is located 21 kilometres from the host platform, making this development the longest subsea tie-back with ESP completed to date.
The equipment selected for the ESP system is described, including downhole, subsea and the topsides equipment. A rigorous testing programme was performed to prove that over such a distance from the variable frequency drives ESP could be successfully operated, controlled and data received.
The experience gained during the development will serve as a guide to future long step-out or deep-water subsea developments by identifying critical components and the operational philosophy developed for the Otter field. Factors limiting the development of fields at greater step-out are discussed.
Conclusions can be drawn on the steps required to implement a successful development and some of the pit falls to be avoided.

Introduction
The Otter field lies in the Northern area of the Northern North Sea on the edge of the Viking Graben area (see Figure 1). The field is operated by TotalFinaElf exploration UK plc on behalf of the joint venture partners Dana Petroleum (E & P) Ltd, Esso Exploration and Production UK Ltd and Shell UK Ltd.
The field was discovered in 1978 by Phillips Petroleum, however the field remained undeveloped until 2002 due to the limited size of the discovery and technical challenges. Operatorship of the field was acquired by Fina Exploration in 1997 and at this time interest in developing the field was renewed. To prove reserves and well deliverability a delineation well, 210/15a-5, was drilled and tested in 1998. The results of this well were encouraging and a development screening study was launched. A further delineation well was drilled in 2000 to confirm a field extension to the North prior to the launch of the development project.
The hydrocarbon reserves in the Otter field are found in faulted compartments of the Middle Jurassic Brent sequence, with the top reservoir at around 2000m below sea-level. The reservoir has good porosity and excellent permeability, with horizontal wells able to produce in the range 15-20,000 bbl/d. The reservoir fluid was under saturated at initial conditions with a gas/oil ratio of 450 scf/bbl, and contains low levels (&lt;0.3%mol) of carbon dioxide and traces of hydrogen sulphide. The reservoir was initially normally pressured, approximately 62 bar above the bubble point. Wells flow during initial stage of production, but require artificial lift once water cut increases or the pressure depletion occurs.

Development Strategy
The development consists of three production wells each equipped with dual ESP and two water injection wells to provide pressure support. A full description of the Otter development can be found in Ref 1.
Prediction of the long term behavior of synthetic mooring lines
Authors: Davies Peter , Chailleux Emmanuel , Bunsell Anthony , Grosjean Francois , Francois Michel 
Published: October 2008

Abstract
The stiffness and short term behavior of polyester mooring lines are now reasonably well understood and these materials are finding many applications offshore. Much less is known about the long term behavior of this and other synthetic materials (aramids, HMPE). This paper presents results from creep and cyclic loading tests on these three materials at different scales, from single fiber up to ropes. The behavior of aramid and polyester is compared with the predictions of a viscoelastic-viscoplastic model which includes bedding-in effects. For HMPE lines it is creep which dominates line design, and data are compared to an existing creep model. New material developments which significantly improve creep performance of HMPE-based ropes are presented.

Introduction
The last five years have seen much development of synthetic ropes for deep sea mooring lines. Polyester has been extensively used offshore Brazil 1. Other installations off West Africa, and more recently the first applications in the Gulf of Mexico, have confirmed the potential of this material.
Permanent moorings require a guaranteed lifetime of at least 20 years, so an in-depth understanding of the long term behavior of the polymer fibers which make up the synthetic components is essential. The loading types of interest are creep (long term constant load), recovery (response after unloading), and cyclic loading at periods in the range from 5 to 500 seconds.
The factors which determine the lifetime of a synthetic rope are the global response, the strain level achieved at a given time and its magnitude with respect to failure strain, and local response due to factors such as abrasion, fatigue, accidental damage and defects. This paper will concentrate on the global response, and the development of models which allow global strain to be determined at any time as a function of loading history will first be discussed. Some recent material improvements will then be presented. The paper concludes with some discussion of local failure mechanisms and work currently underway.

Materials
There are two materials currently attracting interest for deep sea mooring lines, polyester and HMPE (high modulus polyethylene). However, ropes based on several other fibers also offer attractive properties, including aramids (Kevlar, Twaron), improved polyesters (Pentex) and liquid crystal polymers such as Vectran and PBO. Although the latter are relatively expensive at present compared to polyester the material costs may only represent a small part of the overall costs to be considered in the installation and operation of a floating platform. It was therefore considered premature to exclude technically interesting fibers, and Table 1 shows the materials which have been examined in the current study.
Use of Enhanced ATS Pictures for Gulf-Storm Researches
Authors: Fujita T. Theodore , Tecson Jaime J. 
Published: October 2008

Abstract
Hurricanes cause severe damage along the Gulf Coast almost annually. Since two intense hurricanes, Camille and Celia, resulted in severe damage, it became necessary to predict possible damage based on satellite pictures long before ground-based radar is capable of detecting hurricane structure. Presented in this paper is an example of enhanced satellite picture and the extent of hurricane damage assessed by the damaging wind scale proposed by Fujita.

1. Introduction
Applications Technology Satellites (ATS) located 22,500 miles above the equator have been taking pictures of the earth at frequent intervals. Since the orbital period of ATS is selected to be the sidereal rotation period of the earth, it is feasible to monitor development of storms continuously during sun-lit hours. An operational satellite SMS/GOES to be launched late in 1973 will carry an infrared sensor, permitting us to monitor severe storms 24 hours a day.
To make the most use of satellite data, pictures can be enhanced so as to depict detailed structure of storms for their prediction and subsequent disaster preparedness.
It is the purpose of this paper to review potential values of geostationary satellite data and to present a method of storm damage assessment based on the F-scale damage categories.

2. Values Of Geostationary Satellites

In Monitoring Gulf Storms
ATS III, located above the equator south of the United States, is sending pictures back to the earth for every 10 to 30 minutes, depending upon storm situations. These pictures have been put together operationally into time-lapse movies by National Hurricane Center at Miami, National Severe Storms Forecast Center at Kansas City, and National Environmental Satellite Service at Suitland, Md. Basic research on the operational application of satellite data has been conducted by SMRP, Satellite and Micrometeorology Research Project, at the University of Chicago in an attempt to solve problems of storm identification and prediction.
Shown in Fig. 1 is a picture of hurricane Camille shortly before her landing near Gulfport, Miss., causing tremendous wind and water damage. As has been well known, the top of a hurricane is covered with a thick cirrus shield which often appears to be a white disc in satellite pictures. Taking place beneath this white disc are high winds and waves coupled with heavy precipitation, resulting sometimes in practically zero visibility.
Thanks for the development of geostationary satellites capable of looking down upon the earth to scan cloud patterns with 2.5-mile resolution at the sub point. We can now trace back all hurricanes to their spawning ground which may be in the Caribbean or the Atlantic or even in West America. The eggs of potential hurricanes can thus be monitored all-the-way to their hatching ground.
The Appraisal and Development Plan for the Heavy Oil Jubarte Field, Deepwater Campos Basin, Brazil
Authors: Bezerra Marcio  F.C. , Pedroso Carlos , Pinto Antonio C.C. , Bruhn Carlos H.L. 
Published: October 2008

Abstract
Heavy oil production from the deepwater Campos Basin, southeastern Brazil, has comprised a new challenge for Petrobras (Pedroso et al., 2003; Pinto et al., 2003a, 2003b; Bruhn et al., 2003). One of the most recent discoveries in the Campos Basin is the Jubarte oilfield, located off the Espirito Santo State, under water depths between 1,000 and 1,500 m, and containing reserves of about 600 million bbl of 17.1° API oil.
Jubarte field was discovered in January 2001, when a vertical well found 40 m of oil-saturated, Maastrichtian turbidite reservoirs underlain by a thick aquifer. The well was cased and tested, but the recorded PI showed to be insufficient to guarantee commercial oil production.
In order to investigate the actual production potential, the drilling and testing of a 1,076 m-long horizontal well was approved, based on the "Value of Information" approach. The horizontal well recorded a PI 12 times the PI of the vertical well; this proved that it would be possible to produce the Jubarte field heavy oil at commercial flow rates. The appraisal of the area was completed with the additional drilling of two wells. With the same approach, an Extended Well Test, with the horizontal well flowing to an FPSO, was proposed and started operation in October 2002. Again, the obtained production rate was better than the predicted, and the commerciality of the field was declared in December 2002. Based on well log data, core samples, seismic data and interpretation of the extended well test data, stratigraphic and structural analysis were performed, resulting in a complete 3D geological model. Multiphase flow studies and a full field flow model were built, which allowed the forecasting of the field behavior.
With a reliable flow model, supported by a complete uncertainty analysis, the development plan for the whole field was defined. To mitigate the production uncertainties, the first phase will consist of 4 wells only, with different lift systems, connected to a FPSO with a processing capacity of 60,000 bopd.
In this paper we describe the whole process of the discovery, test, appraisal and definition of the strategy to develop the Jubarte Field. Special emphasis is given on the technological challenges that must be overcome to make possible the development of the oil field containing the heaviest oil ever produced from the deepwater Campos Basin.

Introduction
Jubarte Field, discovered in January 2001, is located 77 km off the Espirito Santo State coast, southeastern Brazil, under water depths between 1,000 and 1,500 m (Fig. 1). It contains 17.1°API oil, with viscosity of 14.5 cP at the saturation pressure of 183.5 kgf/cm2. The dead oil viscosity at 20 °C is about 3,000 cP, being the most viscous oil at surface conditions ever produced in Brazil through a wet completion system.
A New Approach to High Accuracy Ranging with Microwaves
Authors: Ragan Lawrence 
Published: October 2008

Abstract
Describes the design, development, installation and operation of a microwave ranging system for use in offshore pipe laying operations. Discusses error causes and correction methods, system design and mechanical design. Maximum non-correctable error due to equipment variations is 0.25 meter. Analysis shows up to 1 meter error due to propagation effects.

1.0 Problem Definition

1.1 Offshore Pipe Locating
The equipment described here may have uses in other areas, but it was designed specifically for use in laying and servicing oil and gas pipelines on the ocean floor. These lines are used to gather and transport the products of offshore wells.
The pipe-laying operation is performed in several steps, as follows:An initial survey is made of the route to be followed. This includes study of other pipes, cables, etc., already in the area, as well as soundings to determine depths, measurements of currents, and in some cases inspection of certain areas by divers. An accurate route map is made; called a "preplot", showing where the pipe is to be laid.Where necessary, the ocean floor is smoothed by dragging, dredging or blasting.The pipe is welded together, wrapped at the joints, and laid on the ocean floor. This is done with a large barge which pulls tension on the pipe against anchors placed by tugboats. The barge has no propulsion system of its own.The position of the pipe is checked with a sonar by a survey vessel.The pipe is buried by another barge. This is done hydraulically, in most cases.
The entire operation is very expensive and down time is quite expensive as well. Hence, reliability and maintainability are very important.
Accuracy is required primarily to conserve pipe. Accurate positioning helps to conserve pipe in two ways. The most obvious, of course, is by laying it in a straight line. The other way is in preventing buckling. If the anchors begin to slip, the barge backs up, and the pipe may buckle. Accurate position measurement gives an early warning of, and evaluation of the extent of slippage. Repeatability is required to lay pipe on the prescribed course, to bury the pipe, and to locate it for later additions, service, or repairs.
Low frequency locating systems such as Loran and Decca not only fail to provide the required accuracy, but are virtually inoperable on a pipe-laying barge due to interference from the arc-welding and h.f. communication equipment.

1.2. Location by Triangulation
The approach taken then, is one of direct distance measurement using microwaves. The distance to two reference points is measured, and the vessel's location is then found by triangulation (fig. l.la). Extreme accuracy is needed when the subtended angle is quite small (fig. l.lb) or quite large (fig. l.lc) in order to accurately determine the vessel's position.

1.3 Previous Approach
Previous equipment designs to measure these distances compared the phase of the sinusoidal modulation waveforms of an outgoing and returning phase-modulated wave to determine the distance.