bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Economic Early Production and Testing System for the Deepwater Gulf of Mexico
Authors: Grecco M.G. , Tein David 
Published: October 2008

ABSTRACT
This paper presents the results of a study which was conducted to show that an Early Production and Testing System is technically feasible and can be economic under certain conditions, providing the oil price, well rate, and duration of production are adequate.
An Early Production and Testing System (EPTS) is a collection of conventional offshore production equipment which is used to producecrude oil from wells which are drilled for the purpose of exploration. The system consists of: a subsea completion tree, a freestanding riser, a buoyant flowline and a moored vessel. The moored vessel provides support for the oil processing equipment and processed crude oil storage.
Produced crude is offloaded into shuttle tankers for sale and thus the generation of, early cash flow.
Besides the early production andcash flow, vital well productivity and crude characteristics are obtained. With the extended well testing, more data can be supplied for modeling the reservoir anddetermining the economics of potential field development. This information will lead to a more accurate characterization of the reservoir, and a better design of the permanent production facilities.
EPTS for various water depths, well production rates, production durations and oil prices were evaluated for the Gulf of Mexico environment. A sensitivity study on these variables was conducted and the results were analyzed to give guidance on the economic use of an EPTS.
The results of the study show that the EPTS can be designed using conventional offshore components andconstructed and installed at a reasonable cost. The concept appears to be technically feasible, even to 8,000 ft water depths.
The EPTS can be economic and provide a positive cash flow, provided the well rate and production duration are adequate for a given oil price. Profits of tens of millions of dollars are possible.

INTRODUCTION
The successful development of an offshore oil field depends on having adequate information about the reservoir production characteristics and an accurate estimate of the field development costs. From thisinformation a decision can be made on whether or not to develop the field and the type of production concept which should be used, to be the most cost effective.
An Early Production and TestingSystem (EPTS) is one method which can be used to supply information to make decisions on the reservoir'sproduction characteristics and what type of field development concept would be most cost effective. These systems are designed to remain on location during the exploration and delineation phase of a field development. The initial exploration well and subsequent delineationwells are produced for an extended period of time so that the wellproduction characteristics can be defined and the generation of an early cash flow can be established.
The purpose of this study is to identify under what conditions it would be economically beneficial toconduct an extended test or establish early production utilizing an EPTS.
Dewatering and Hydrocarbon Commissioning of 36-in. Forties Charlie to Cruden-Bay Pipeline
Authors: Tanner R.N. , Putnam J.S. 
Published: October 2008

ABSTRACT
This paper summarises the activities involved in the dewatering, oil fill, and hydrocarbon commissioning the 172km (107 mile) 36" Subsea Forties Export Pipeline, (36" sealine), from Forties Charlie, (FC), to Cruden Bay, (CB). The starting point for this paper is a discussion of the factors affecting the selection of the dewatering/oil fill strategy adopted. The consequent hardware requirements, and equipment selection, are then described, followed by a brief description of the status of the pipeline prior to the commencement of it's dewatering and oil fill. Finally a summary of the actual dewatering/oil fill operation, and the subsequent transfer of FC export flow from an existing 32" sealine to the 36" sealine is given.

INTRODUCTION
The original 32 inch Forties Crude CM Export Pipeline was constructed between 1973 and 1975 to transport crude oil from the Forties Field in the United Kingdom (UK) Sector of the North Sea to the shore at Cruden Bay north of Aberdeen on the Scottish coast.
Once ashore the crude oil is transported by a 36 inch Iandline for stabilisation at Kinneil, Near Edinburgh, followed by storage and export via the Hound Point terminal, or further processing at the BP Grangemouth refinery. Fig. 1 shows the layout of the Forties Pipeline System (FPS), of which the 32 Forties Crude Oil Export pipeline (32" sealine), formed part.
Originally the FPS transported crude oil from the Forties Field only. Since 1983 however, when crude from the South rae Field entered the FPS, Crudes from a number of North Sea fields have been transported to utilise the ullage left by the decline in production from the Forties Field. The number of crudes transported by the system grew steadily after 1983 and by 1988 had reached nine.
Internal inspection of the 32 inch pipeline during 1988 revealed that significant corrosion of the pipe had taken place and while the pipeline remained fit for its original purpose, it was predicted that progressive reductions in operating pressure would be required as corrosion continued, such that the pipeline could reach a capacity limitation for existing entrants during 1991.
Various solutions were put forward, including the use of flow improvement chemicals, partial or total replacement of the 32" pipeline or replacement with a 36 inch pipeline. The chosen solution which minimised production downtime, provided for longevity of operation, and provided a business opportunity for the transportation of further crudes from other fields was to replace the 32 inch pipeline with a new 36 inch pipeline.
The Project to replace the pipeline was sanctioned in June, 1989 with pipelay commencing in April 199o, the timing being governed by the predicted down rating program me of the existing pipeline, together with the anticipated high level of North Sea construction activities during the 1990's.
Use of Sized Salt Mud in Horizontal Completions
Authors: Sargeant J.P. , Siamos Anastasios , Eriksen N.H. 
Published: October 2008

ABSTRACT
Norsk Hydro has used a sized salt drilling mud in the completion of three horizontal wells and five open hole gravel packs. This paper explains why this system was chosen, describes the mud properties and reviews the different completion operations used.

INTRODUCTION
Three horizontal wells were drilled into thin oil layers between aquifers and gas caps and completed with prepacked screens for sand control. Two of the wells are on the Troll field, while the third is on, the oseberg Gamma North structure. The objective in each case was to produce at high rates with a m1nimum drawdown in order to reduce gas coning. It was critical for efficient reservoir drainage that, the entire section produced. This implied that all mud cake should be removed prior to production to prevent impairment of the screen and reservoir.
The five vertical open hole gravel packs are installed in the Troll subsea wells that supply the Oseberg field with gas for pressure maintenance of the main 011 produc1ng reservoir (TOGI) successful completion of these wells was critical for pressure maintenance and production on Oseberg.
In order to achieve the high completion efficiency required, the sized salt mud was chosen because apart from its good properties as a drilling fluid, the mud cake was easily dissolved in undersaturated brine. Hence this avoided the use of acid with its detrimental corrosive effect on the chromium steels used in the completions.

HISTORY
Prior to the horizontal well drilling program, a calcium chloride brine system with calcium carbonate for weight and fluid loss control had been used on Troll gravel packed appraisal wells. The size distribution of the carbonate particles was specified in order to minimize fluid loss in this reservoir which has several darcies permeability. The filter cake was removed using hydrochloric acid before the gravel was placed. Injection into the reservoir was obtained very quickly, and it was normal to pump the gravel with complete losses. This system was considered to be a success despite the need for post pack acid jobs.
Saturated salt systems had been used for many years for various applications including drilling horizontal wells (ref.l&2). We had used a saturated salt system on the Oseberg field as a kill pill. The pill consisted of saturated NaCl brine, Xanthan polymer, salt, lignosulphonate and magnesium oxide for fluid loss control. Laboratory testing on cores indicated, however, that this system caused formation damage. The return permeability was reduced to 87% and 54% of original in short and long term tests receptively. The lignosulphonate and magnesium oxide were replaced by a modified corn starch recently made available, which in addition to being non-damaging also enhanced the fluid theology.
To gain experience with this system, it was used to core the reservoir section on an exploration well. We discovered that instead of the expected thin, easily dissolved filter cake, we obtained a thick rubbery filter cake that we could not dissolve.
Automatic Control of Bulk Cement Tank Levels
Authors: Wienck D.A. , Pitts A.J. 
Published: October 2008

ABSTRACT
The delivery of dry bulk cement to the cement mixer can be a difficult task. The level of cement in the surge tank must be controlled as the flow into and out of the surge tank changes. An automated system has been designed that is capable of maintaining a proper level in the surge tank. The system is primarily designed for use on offshore rigs and reduces the need for constant attention by an operator.
This paper will cover:the bulk level control system requirements,the selection of components and,the operation of the system.

INTRODUCTION
In the past, steady flow separators on offshore rigs were operated by fairy available person on the rig. Typically, this was any rig crew member who was not busy during the cementing job. This meant that often the operator was untrained and, due to the turnover of personnel, rarely the same person twice. To determine the level of cement in the tank, the operator used the sight glasses which were often dust covered or tapped on the tank with a hammer to determine the level by a difference in sound.
To overcome these operating problems, an automated bulk level control system was designed to control cement flow into the surge tank. The system monitors the level in the surge tank and adjusts the inlet flow as needed.

SYSTEM REQUIREMENTS
The normal practice of handling bulk cement is for the operator to watch a dust covered sight glass and attempt to keep a uniform Level of material in the steady flow separator based on this sight reading. Some rigs are equipped with a scale to weigh the steady flow separator (surge tank). This tells the operator the weight but not the level in the tank. Possibly 10%of rigs have scales. Using the scale, a lightweight cement blend can overfill while the same weight of heavier blend may result in the correct material level.
Proper control of the material is not an easy job. Dust collects on the inside of the sight glass and makes the surge tank look full when it is empty. The light installed on the inside of the tank helps, but frequently burns out. Typically, the only reliable indication of the level in the tank is found by tapping the outside of the tank with a hammerand trying to listen to the difference in tone between full and empty at that location.
Several undesirable events can happen with inexperienced operators. The surge tank could unintentionally empty. When dry cement stops flowing to the cement mixer, this causes a drop in the density of the cement slurry.
Alternately, the surge tank could overfill. This could plug the vent piping with dry cement, making it difficult to remove the dry cement or the excess conveying air from the tank. The result is change in the density of the cement slurry.
Ocean Bottom Receiver Location: A Model-Based Solution To Locating Receivers On The Ocean Bottom By Using Geophysical Data
Authors: Edington B.L. , Starr J.G. , Cafarelli W.J. 
Published: October 2008

ABSTRACT
The ocean bottom cable method (OBC) of seismic data acquisition involves placing stationary receivers on the ocean floor and using an air gun array towed by a separate boat as an energy source. The location of each receiver group after deployment is a function of water depth, prevailing water currents and the dynamics of the cable falling through the water. Ocean Bottom Receiver Location (OBRL) positions the receivers accurately by utilizing first break information, estimated water and water bottom velocities, shot locations and water depths.
The major advantages of the OBRL method are speed and accuracy of the solutions and that no additional equipment is required for locating the receivers. In addition, the near real time processing of the data allows for adjustments in the shooting and deployment patterns to assure proper subsurface coverage.

INTRODUCTION
The ocean bottom cable (OBC) method and its use for 2-D and 3-D surveys has been discussed previously (Rigs by et al., 1987). This method is currently used in water depths ranging from very shallow to 100 meters and is not impeded by obstructions such as drilling rigs, production platforms, or boat traffic. Figure 1 depicts a recording boat anchored on prospect and attached to the receivers on the water bottom via a telemetry cable. The gun boat towing a short air gun array is separate. This configuration allows for work in obstructed areas and versatility with the acquisition geometry. The minimum configuration of an OBC crew is:The source boat towing only an air gun array and thus Highly maneuverablethe cable boat, responsible for cable deployment and retrieval,the recording boat carries the dog house and all recording Instrumentationa chase boat, used as a water taxi and picket duty along The deployed cable.
Stationary receivers on the water bottom allow for versatility with the acquisition geometry. Patch, swath or radial designs are commonly used in 3-D surveys. The swath technique involves laying out approximately 24 km of bottom cable in one or two lines and recording multiple shot lines parallel to the eceiver cable as shown in figure 2. Figure 3 depicts a patch geometry in which several receiver cables (in this case 4) are laid out with multiple shot lines orthogonal to the receiver lines. To make full use of the acquisition geometry, receiver and shot positions are predetermined on a map before the survey commences. The cable boat deploys the receivers at these locations, however, currents and other factors cause the receiver positions on the water bottom to be different than that of the surface drop position. It is necessary in an OBC survey to locate the receivers on the water bottom. OBRL locates the receivers accurately by using first break analysis recorded by the receiver groups and a single air gun or air gun array as a source
Modelling The North Sea Through The North European Storm Study
Authors: Peters D.J. , Shaw C.J. , Grant C.K. , Heideman J.C. , Szabo D. 
Published: October 2008

ABSTRACT
The paper describes the development of a hindcast database of wind, wave and current parameters for the North Sea and Eastern Atlantic ocean. The study, which was a joint industry project funded by u group of nine oil companies and two government agencies, was initiated to enable consistent metocean criteria and operational statistics to be derived for offshore areas of the UK, Norway anti the Netherlands.
The wind, wave and current modeling work, which was carried out by a consortium office European technical institutes is described. In particular, a description is given of the careful development of the wind fields during the 2S-winter period of the study especially during the severe winter and summer storms. The relatively large amount of measured field data which is available for the North Sea enabled detailed comparisons to be made with modeled data und highlighted the cure which needs to be taken when comparing the two and in calibrating verifying models.
An aspect of the study which is probably unique is the formation of a follow-on study which adds new storms to the database as they occur thereby enabling questions concerning the influence of some of the severe recent storms to be readily answered when preparing design criteria for certification purposes.
The NESS study is an application of new technology to a mature area. Results of the study have been included in the establishment of design wind, wave, and current criteria for North Sea installations. In addition the database is proving to be u valuable source for assessing the reliability of existing structures and for improving loud calculations on structures by enabling the uncertainty und variability in environmental conditions to be quantified.

INTRODUCTION
The North European Storm Study (NESS) was initiated in order to produce a high quality hindcast database of winds, waves, storm surges and depth-integrated currents for the North European continental shelf (Figure 1.1). The project was funded by eleven Participants (nine oil companies, and two government departments) and the work was carried out by meteorological, and oceanographic institutes in five European countries.
To be successful a major hindcast project needs to have certain attributes. First amongst these is the technical expertise of the members of the modeling institutes, and the models which they will be using. Second is the availability of high quality measurements {it fixed locations with which the models can be calibrated, and verified. Furthermore, there needs to be a sufficient number of motivated participants to manage and carry through the project as well :is to contribute on technical issues as they arise. The project took more than five years to complete at a cost of over £2. 1 million, and has resulted in ii major asset to the industry from which both significant cost-savings, and improvements to the safety of operation scan be expected for many years.
Exploitation Of Marine Current Energy
Authors: Garbuglia Emanuele , Rosa Alberto Dana , Berti Dario 
Published: October 2008

ABSTRACT
This paper describes the results of a feasibility study regarding the exploitation of marine currents in the Strait of Messina (Italy). The high kinetic energy contents of these currents suggest the development of some exploitation system. The technical solution, proposed in the study, consists of seabed installed vertical axis turbines, which are able to optimize energy extraction. The work performed at this stage included a basic design of the system and a preliminary evaluation of the Environmental Impact. A costs/benefits evaluation showed that electricity produced by the proposed system is competitive with that based on other energy sources, conventional ones but mostly renewable ones. Moreover fresh water, considered in alternative to electricity production, could be produced at costs comparable with present supplies by shuttle tankers.

INTRODUCTION
Marine currents represent a large renewable energy resource and can give a significant contribution to fulfilling energy demand, with emphasis put on local supplies. Among the ocean and renewable energy resources marine currents have certainly not been given enough consideration by researchers and energy authorities. The reason can probably be found in the fully marine characteristic of the systems suitable for exploiting marine currents, if compared with either OTEC, wave or tidal energy systems which are essentially land based. As in all the other renewable and non-conventional energy resources, so the energy extracted from marine currents can hardly exceed a few percent of the global energy consumption, even if in several cases it can play an important role in counteracting energy shortage while coping with environmental constraints in coastal areas or isles, by integrating or substituting energy systems based on conventional resources, like oil, gas or coal.
The technical interest of the study stems from the high kinetic energy content of marine currents in the Messina Strait (South of Italy) and from a socio economic context that suggests following the logic of local development, The study, even if targeted at a particular application, is aimed at proposing general guidelines and technological solutions for dealing with analogous situations of exploiting marine currents. The size of the proposed hydro-generator (1 MW electric) and the modular system approach make this solution suitable in various contexts,

THE SITE

Geography
The Messina Strait (fig. 1) is a small sea channel about 30 km long with a minimal width of 3200 m, that separates the Italian mainland from the island of Sicily, connecting the Ionian and Tyrrhenian Seas. It presents a variable bottom profile with a depth of up to 1500 m. The profile is characterized by the presence of a transversal sill, in the northern part of the strait which is also the narrowest. In correspondence of this sill the depth rapidly reaches the minimum of about 80 m over a length of about 7 km. This point constitutes a net separation between the two seas and a "bottle neck" for the water flow.