bluuebunny/crossref_metadata_2025_split huggingface dataset:
MTU - The Multi Test Unit for Investigating Offshore Separation Problems and Optimizing the Gas/Oil/Water Separation Process
Authors: Gramme P. E. , Dybdahl B. , Holt Ø. , Friedemann J. D. , Riise B. 
Published: December 2007

Abstract
Multiphase separation and flow is governed and influenced by phenomena and mechanisms that are strongly dependent on fluid specific properties. A typical example is phase dispersion which is composed of mechanisms like droplet breakup, droplet coalescence, phase inversion and sedimentation/ flotation, which in turn depends upon the nature of the oil/water interface determined by the surface active components of the oil.
There exists a vast number of surface active components in a crude oil comprising of original components like asphalthenes, waxes, inorganic particles and napthenic acids and foreign components like production chemicals (demulsifiers, anti foam chemicals, asphalthene inhibitors, scale inhibitors etc). The composition of an oil is therefore highly specific and therefore also the separation and flow properties of the oil.
In this paper it will be shown how large the variations in the behavior of crude oils can be with respect to their individual separation and flow characteristics. This paper will also focus on what fluid specific information is needed for characterizing the separation and flow properties of an oil and serve as basis for process selection and design.
Tentatively, several methods can be used for obtaining such information. This paper presents a new proven approach for performing separation tests at real conditions, by using a multi test unit (MTU). The use of the MTU will be compared to other methods like "bottle tests", laboratory scale tests, flow loop testing and full scale testing. The advantages and limitations of the various methods will be discussed. By comparing data from oil fields and corresponding test results it will be shown that some of these methods can be used to predict the real process behavior of a fluid. One of the most realistic methods is the use of the MTU. The details of performing a MTU test will be presented, as well as how this test unit can be applied in order to reveal the separation and flow properties of a fluid. Currently, two main areas of interest have proved the suitability of performing tests with the MTU: Firstly, it can be applied in process optimization and as a trouble-shooting tool. Hence, testing and optimization of production chemicals (such as demulsifiers and anti foam chemicals) can be done in a realistic and effective manner. Secondly the MTU can be used in the exploration phase in order to get valuable data as input to process design for new field developments.
Eastern Trough Project Heron Cluster Operations and Producing from Complex HP/HT Subsea Fields
Authors: McClung G. , Coote L. , Davidson W. 
Published: December 2007

Abstract
This paper examines some novel aspects of operating an integrated multiple ownership development operated by BP Amoco consisting primarily of subsea tiebacks to a central processing facility. The complexity factor is high, as some of the reservoirs are high pressure/high temperature (HPHT).
Reservoir conditions for the Shell/Esso fields within this operating regime are particularly severe and a significant amount of Production Chemistry research was carried out up front to meet this challenge.
This earlier research work has now been built on with the benefit of experience and utilizing a methodology known as Focused Results Delivery (FRD) to create a paradigm shift in projected operating expenditure costs.
The producing potential of the wells has also been significantly increased by the use of Finite Element Analysis (FEA) to model critical component stresses.
The Applications of Advanced Computing Techniques to Oil and Gas Facility Optimisation
Authors: Murray A. , Neuroth M. , Stronach A. F. , MacConnell P. F. A. 
Published: December 2007

Abstract
This paper considers the potential impact of advanced computing techniques on oil and gas facility optimisation. Specifically, the application of Artificial Intelligence (AI) techniques is considered. Following a brief introduction to the AI techniques available, possible applications in the oil and gas industry are considered.
The paper builds on the assertion that AI can offer substantial savings to facility operation by citing two case studies of AI application. The first study considers the use of Artificial Neural Networks (ANNs) for the prediction of chemical injection for pipeline operation, and the possible saving that are available. The second study considers the use of a Fuzzy Logic System (FLS) for the optimisation of a pipeline pump station control strategy. Finally, the problems and possibilities offered by AI are discussed.
Deepwater Tie-ins of Rigid Lines: Horizontal Spools or Vertical Jumpers?
Authors: Corbetta Giovanni , Cox David S. 
Published: December 2007

Abstract
Movement towards deeper waters and harsher environmental conditions has, and will, require the continuous development of new technologies. Especially the design and operation of remote tooling to complete subsea field developments.
One of the principal problems faced during both the design and operational phases of a project is the definition of methods and systems to perform the tie-in of production lines to subsea facilities. This, in fact, influences some critical decisions such as:
Type of lines (rigid/flexible); Structure layout (tie-in porches and interfaces); Installation method (first- or second-end connections).
Sonsub International has developed different systems to perform remote connections of either flexible or rigid lines.
Among these, special attention was paid to rigid line connections since this is the preferred option of the industry because of both technical and economic reasons. This has led to the development of a dedicated set of tooling able to perform tie-ins of rigid lines using standard spool pieces and bolted flanges.
Sonsub simultaneously investigated the concept of vertical jumper installation in deep water as part of a larger development study.
This paper presents a comprehensive comparison between the horizontal (spool piece) tie-in versus the vertical jumper method.
The evaluation will include an overview of the systems considered and will outline advantages and drawbacks, both technical and financial, of the two solutions.
The Alwyn North Triassic Development: Developing a Large Gas-Condensate Reservoir While Making Maximum Use of Existing Facilities
Authors: Murray H J , Schirrer L , Anfray R , Bordmann V 
Published: December 2007

Abstract
The Alwyn North Triassic reservoir is a deep gas condensate accumulation underlying the currently producing Alwyn North Brent and Statfjord reservoirs in quadrant 3 of the Northern North Sea. Two early exploration wells in quadrant 3 had encountered Triassic gas-bearing sands with only the second one, a subsea well, tested but at a non economical rate. However, in 1995 a third well, drilled from the Alwyn North platform, successfully tested at 1.3 Mscm/d of gas and 3,300 stb/d of condensate. A platform extended well test (EWT) was then performed by simply connecting the well to the Alwyn North gas manifold and gas processing train to obtain long term production performance.
Following encouraging results from this well, an extensive appraisal programme was embarked on consisting of drilling three further platform wells and connecting them to production to provide information on long term reservoir performance. In addition, sand frac jobs were performed on two of the wells to assess productivity improvement, access to additional reserves and technical feasibility.
Successful results from the appraisal programme were then used as the basis for a full field development plan for the Triassic, the main element of which is the drilling of additional wells to optimise recovery of the Triassic fluids. The new platform wells will be challenging (total drilled lengths of up to 7800m with depleted sands above Triassic) and an upgrade of the Alwyn North drilling facilities is required. The first platform development well was spudded in April 1999 and peak Triassic production rate is anticipated to be around 5 Mscm/d.
Given the relatively poor reservoir quality and well productivity and encouraging results from sand frac jobs performed during appraisal, improved recovery techniques of hydraulic fracturing and multi-lateral wells are being considered in the development plan. All Triassic wells will be produced via the existing Alwyn North production facilities which require only minor modifications.
It is also planned to debottleneck the high pressure gas train on the Alwyn North platform to ensure that the significant volumes of additional gas brought by the Triassic development can be produced without facilities constraint.
This paper describes how information from the extensive appraisal programme was used to define and optimise the full field development plan whilst making full use of the existing Alwyn North facilities, and upgrading where necessary. Integrated field development aspects (reservoir, drilling and facilities) are presented in this paper.
Synergies between two Neighboring Major Developments
Authors: Stubbs John , Fort Joel 
Published: December 2007

Abstract
The Elgin/Franklin and Shearwater Developments represent a combined investment of over £2 billion to exploit the HP/HT reserves in the Central North Sea. The parallel development of these two major projects and the associated infrastructure has presented the project teams with a set of new and unique challenges, which have required a combined approach in many areas to produce new answers that have yielded substantial reductions in overall development costs.
The results of this synergy are summarised in the paper and cover the work completed to date. The paper summarises the options examined leading to the selected development concepts, the common gas and liquid evacuation systems, and the associated commercial agreements necessary to define the current and future relationship between the 10 co-venturers involved in the combined developments. The paper rdso summarises the future opportunities for further synergies between the two operators Elf Exploration UK plc and Shell UK Exploration and Production.
Increased Oil Recovery by Economical Pilot Hole Delineation of Reservoirs Using 3D Rotary Drilling Technology
Authors: Gaskin George J. , Laastad Harald , Garvik Ina 
Published: December 2007

Abstract
This paper will focus on the problems encountered directionally when drilling with conventional directional equipment, and demonstrate how, by use of a three dimensional rotary steerable system, successful, cost efficient reservoir delineation was attained, resulting in increased oil recovery and allowing improved field development, both technically and financially.
Two completed wells, F-4AH completed end of 1997 and G-2H drilled late 1998, with similar reservoir faulting and reservoir delineation requirements, will be compared to demonstrate the technical and financial gains made by use of a three dimensional rotary steerable system versus conventional and two dimensional steerable technology.
Resulting increase in oil recovery, future potential for more radical directional profiles and planned improvements will be presented, in the pursuit of further cost saving and increased oil recovery in this challenging drilling environment, where extended reach ‘designer’ type directional profiles well configurations are standard requirement.
Optimization of Mud Temperature and Fluid Models in Offshore Applications
Authors: Kårstad Eirik , Aadnøy Bernt S. 
Published: December 2007

Abstract
High pressure high temperature deep-well drilling is often associated with several unusual problems. Some important factors are pressure control and interpretations of well signals. Mud ballooning, or apparent mud loss during circulation and a pit gain after stopping the circulation, is known to complicate the interpretation of the pore pressure.
In this study, an analytical model is developed by describing the energy balance in a circulating well. Input of energy due to rotation of the drillstring and pumping of the mud are included. The effect of having a riser in offshore applications is also included.
It is shown that for most cases there is a net flow of energy from the formation to the surface. In offshore applications there will always be a heat loss in the riser.
It is also shown that heat transfer from the well is strongly related to the average fluid temperature in the well. Calculating the energy balance provides important information on temperature- and fluid density behavior.
Enhanced Deoiling Hydrocyclone Performance without Resorting to Chemicals
Authors: Sinker A B , Humphris M , Wayth N 
Published: December 2007

Abstract
There are many produced water deoiling hydrocyclone systems operating today that do not meet the required overboard discharge water quality specification. Common reasons for this include long term changes in field conditions, adverse interfacial chemistry (generally caused by a "cocktail" of chemical additives), small inlet dropsizes or sub optimal deoiling hydrocyclone liner types (e.g. large diameter geometries).
The most common solution to these PWT problems is to implement a chemical injection programme which although can be successful, has a high operating expenditure requirement and can often be more harmful to the environment than the oil it was designed to remove. There is also a general industry initiative to minimise the use of production chemicals in a response to the belief that new legislation governing toxic chemical and dissolved hydrocarbon discharge is imminent.
This paper describes a technology which has been developed by Cyclotech to significantly improve the performance of produced water deoiling hydrocyclone systems without resorting to chemicals. The concept is based on precoalescing the inlet oil dispersion to produce a coarser drop size distribution prior to hydrocyclone entry. Field trials have demonstrated that the technology can improve the deoiling performance by as much as 220%. It requires no external control or power source; displays a marked insensitivity to solids fouling and can be easily retrofitted into existing systems without the need for any major vessel or pipework modifications.
The technology is aimed at existing systems which do not meet discharge specification, or require excessive chemical dosing to do so and at new-build systems by extending the applicability of hydrocyclone based solutions to heavy oil, condensate and other historically marginal applications.
Numerical Modeling of a Triple Porosity Reservoir
Authors: Gurpinar O. , Kalbus J. , List D. 
Published: December 2007

Abstract
The triple porosity reservoir investigated is unique with its highly heterogeneous carbonate characteristics. The largest hydrocarbon bearing formations are not only naturally fractured, but also highly vuggy. Special relative permeability, capillary pressure, and compressibility relationships were developed to simulated multi-phase flow in this triple porosity system. Well and interference tests were re-analyzed at several stages in the project to provide input to geology on fracture properties and later to condition the fracture properties coming from the geologic model. The calibrated model acceptably matched the historical pressure and the production of oil, water, and gas for the reservoir complex.
Another Waterfrac Scenario: An Effective Way to Stimulate Shallow Oil Reservoir
Authors: Gu Fagang , Yang Hong , Liu Yongshan , Jiang Jianxun , Wu Shuqiang 
Published: December 2007

AbstractThe successful use of waterfrac to tight gas reservoirs was presented by M.J. Mayerhofer et al[1–3]. However, its application to stimulate permeable oil reservoirs is not reported to our knowledge scope. This paper presents the application of waterfrac to a shallow oil reservoir with low permeability, reservoir M of Laojunmiao oil field (the oldest oil field of China). The average permeability of reservoir M is 24.2 mD. The use of waterfrac to the permeable reservoirs is a different scenario from that to tight reservoirs because the higher fracture conductivity is required in order to ensure the fracture's flow capability. The more than forty-year history, development, optimization and application effect of waterfrac to reservoir M are given out in this paper.
Feasibility of Downhole Oil/Water Separation and Reinjection in the GOM
Authors: Suárez S. , Abou-Sayed A. 
Published: December 2007

Abstract
A study of the feasibility and applicability of Downhole Oil/Water Separation and Reinjection Systems (DOWS) for the GOM is presented. According to reservoir simulations, oil production increases when applying DOWS. Also, an additional pressure boost at the exit of DOWS is enough to lift the separated volume to surface. In contrast, without DOWS, it is necessary to rely on artificial lift to achieve well production. Targeting reasonable injectivity can provide commercial and available equipment capable of injecting water above the injection zone.
Determination of Injection-Production Ratio Size by Type-curve Analysis
Authors: Dong Jianxia , Zhai Yunfang , Yang Jing , Zhao Chunshen 
Published: December 2007

Abstract
Many oil and water wells are distributed over the all developing reservoirs, of which one well's pressure test data are controlled by multiple well system. People used to solve this problem by taking testing well as a single well system with constant pressure or closed outer boundary. This paper touches upon the outer boundary with constant rate, that is, the effect of multiple well system on testing well is reflected on the injection rate at the outer boundary of testing well, whose relation with the production rate of testing well is Injection-Production Ratio (IPR) of the drainage area. Obviously, such dealing reflects the mutual relationship of oil wells and water wells more truly and universally. For example, closed boundary can be regarded as a special case of outer boundary with constant rate (when IPR=0).
A new type-curve is presented for considering IPR. Using it on well test analysis, not only the usual well and reservoir parameters can be obtained, such as permeability, skin factor and wellbore storage constant etc., but only yield IPR in drainage area of testing well. The practicality of this type-curve is proved by the illustration of test data from Daqing Oil Field.
This paper has successfully solved the well test analysis problem of multi well system, and it is of great importance in guiding well test data interpretation, pattern modification and injection-production balance analysis for present waterflooding reservoirs.
Analysis of Capillary Imbibition Recovery Considering the Simultaneous Effects of Gravity, Low IFT, and Boundary Conditions
Authors: Babadagli T. , Al-Bemani A. , Boukadi F. 
Published: December 2007

Abstract
Capillary imbibition is the dominating recovery mechanism in naturally fractured reservoirs if matrix is water wet and continuous supply of water through fractures exists. The mechanics of the process still needs clarification for complex conditions. Matrix boundary, i.e., the contact areas of fracture fluids with matrix blocks, is one of the causes of this complexity. Capillary imbibition rate and ultimate recovery are significantly affected by the partial contact of water with the matrix due to phase segregation in fracture by gravity or impervious layer covering some part of the matrix.
This study aims at analyzing the recovery behavior experimentally for different boundary conditions and proposes remedies to increase the ultimate recovery. Berea Sandstone samples saturated with two types of oil are exposed to counter-and co-current capillary imbibition at ambient temperature and pressure conditions. Matrix boundary conditions, i.e., the matrix-water contact areas, are changed by covering the sandstone sample surface using epoxy. The oil recovery in non-contacted area of the matrix is due to gravity segregation and also re-imbibition of water that is already imbibed by the matrix blocks. To remedy low oil recovery from the parts of the matrix where no contact with water exists, the same experiments are repeated using low IFT solutions. It is observed that the low IFT solution yields in higher oil recovery from the non-contacted part of the core sample. But, the recovery rate decreases when the low IFT solution is used instead of brine especially for the unfavorable boundary conditions.
Case Study: Coalbed Methane Automation System for River Gas Corporation
Authors: Robertson Steve K. , Pool Mike , Farrens Michael J. , Butts Tammie J. 
Published: December 2007

Abstract
Can an independent producer fulfill a vision to develop and produce a coalbed methane gas field that covers two hundred square miles in a remote desert plateau in the western United States? This paper will answer that question as well as provide answers to other pertinent questions, such as, "What tools would be available to the operator to efficiently and safely produce the wells?" And, "Would the tools allow for future expansion and/or allow new technologies to be incorporated into the system cost-effectively?"
This case study will show how River Gas Corporation was able to successfully meet their needs with an automation system that was jointly developed with an engineering/ manufacturing company. All phases of the project, from its inception in 1991 with a 13-well pilot project to a planned 600-well development will be discussed. Innovative solutions successfully answered the above questions and allowed the system to evolve to meet the continuing changes in expansion and production needs.
Coiled Tubing Ultrashort-Radius Horizontal Drilling in a Gas Storage Reservoir: A Case Study
Authors: Stiles E. Kevin , DeRoeun Mark W. , Terry I. Jason , Cornell Steven P. , DuPuy Sid J. 
Published: December 2007

Abstract
The subject paper is a review of the philosophy, planning, execution and results for the first successful Coiled Tubing Drilling ultra short radius horizontally drilled well into a gas storage reservoir. The paper will seek to describe the process and results for the just mentioned areas.
The philosophy behind CTD and the idea of using it as a tool to enhance gas storage deliverability and the associated costs are considered. This well achieved an 800% increase in gas deliverability after sidetracking, as compared to the original wellbore. The idea of rate of penetration enhancement is strongly conveyed to help the audience understand how this drives drilling parameters and hence, cost.
Planning for CTD operations is discussed and includes a geological discussion. The use of Coiled Tubing and the BHA used to perform this operation are discussed. One tool for several functions drives down cost by reducing process steps.
Execution of the project from mobilization to demobilization is briefly discussed as are lessons learned. Ideas are suggested for further improvement. Some of the issues identified to date will be much more refined prior to paper delivery. This is due to the idea that more work is on the immediate horizon
The first well (KW-34) was re-entered and sidetracked in September, 1998.
"DIP" Fire Fighting and Blowout Control System
Authors: Armanda Davorin , Kovacic Ante , Posavec Vjekoslav , Seletkovic Danko 
Published: December 2007

Abstract
The uncontrolled blowouts of oil, gas and geothermal waters are one of the major problems encountered in oil and gas exploration and production. The problem is even more complex if the flowing fluid contains aggressive components (hydrogen sulphide H2S, carbon dioxide CO2, mercaptane). It is almost the rule that fire follows the uncontrolled well blowouts, where the following problems are encountered:
Efficient fire fighting on uncontrolled blowout wells Fire fighting with existing devices (without additional investment) Fire fighting meeting ecological requirements (pollution should be reduced to the minimum). This is article is describing the fire fighting and blowout control system on oil and gas wells called "DIP ".