bluuebunny/crossref_metadata_2025_split huggingface dataset:
Methanol Losses to the Hydrocarbon Phases in Offshore Pipelines and its Effect on Economics
Authors: Bruinsma D. F. M. , Notz P. K. , Desens J. T. , Sloan E. D. 
Published: December 2007

Abstract
Methanol is the most commonly used hydrate inhibitor in offshore pipelines. The amount of methanol that is lost to the hydrocarbon phases and the implications that this has on the flow assurance strategy and the economics of offshore developments are presented. Methanol losses to the hydrocarbon phases are greatest in pipelines with small amounts of water. For cases of high methanol losses, nonvolatile or thermal inhibition methods may be more economical. The importance of accurate predictions of methanol losses is discussed along with the need for experimental data. An experimental technique for measuring methanol partitioning between aqueous and hydrocarbon phases is discussed. Comparisons between predictions and data are made for methanol partitioning between aqueous and hydrocarbon phases of live fluids.
Scarab/Saffon Subsea System: Design and Installation Aspects
Authors: Ellaithy Wael F , Gaber Mohamed , Gomaa Adel , Vermeulen Ed 
Published: December 2007

Abstract
The Scarab/Saffron field development is the first deepwater field in the Mediterranean. To present day standards the water depth at the field location is not extreme and the pipeline system can be installed by "conventional" methods. The total system comprises a large number of components, such as two large diameter export lines, a large PLEM, two manifolds, eight 10"in-field flow lines, umbilicals and their termination units, flying leads etc. However, the design and installation presented some other challenges to the project team and the Contractors. The system is installed in an area that is seismically active and has a number of highly unusual seabed features. Seismic aspects played an important role in the layout of the system and in the design of some of the foundations of the equipment. Up to now few fields have been designed in seismically active areas and novel techniques were used to the design of some of the components. The challenges are in the variations in water-depth, (0 to 650 meters), in pipeline diameter ( 4 inch to 36 inch) and the different types of umbilicals. No single marine vessel can perform all the installation activities for such a wide range of pipeline sizes and sub sea system components. Flat bottom derrick / lay barges, a semi-submersible installation vessel, a small diameter pipeline installation vessel and other marine construction installation vessels were employed to perform the installation activities of the Scarab / Saffron field development. The planning of the fabrication, delivery, testing, installation and commissioning in a relatively short time presented a major challenge to everybody working on the project. This paper presents details of the pipeline system and the considerations that led to the field layout. Methods of installation and vessels used are described as well as captured lessons learnt.
Geostatistical Prediction of Sand Distribution of Gas Reservoir in Jilin, China
Authors: Qiu Li-Wei , Yang AnPing , Long Sheng-Xiang , Kang Zhi-Jiang 
Published: December 2007

Abstract
This case study involves sand distribution prediction for the Gujiazhi and Houwujiahu gas fields in Jilin Province, China. Initial data analysis involved correcting and calibrating the well logs. Log data from 74 wells were available from the Gujiazhi field and the Houwujiahu field. This initial process also established 3-D porosity, permeability and clay volume models for each field. The Gujiazhi grid has a cell dimension of 100×100×2 meter, Houwujiahu grid 100×100×1 meter.
Geostatistical inversion was conducted for a 3-D seismic volume covering both fields. Synthetic resistivity logs were generated and converted to pseudo-impedance in time, the derived reflectivity was convolved with a wavelet, and the synthetic seismogram correlated with actual seismic traces. This process was allowed to iterate until a satisfactory correlation was reached. One VSP was used for the initial time-depth conversion, and the time-depth relationship for each well was subsequently time-adjusted until the synthetic seismograms matched the actual seismic, allowing a reasonable lateral velocity variation. A common wavelet was extracted for all the wells. With the optimized time-depth control and common wavelet, resistivity inversion was conducted for the 3-D seismic grid. A 3-D reservoir geology model was generated by co-kriging, using the well log data as hard data and the inverted seismic data as soft data.
The 3-D reservoir geology model from well logs showed high vertical resolution but poor lateral resolution, while the 3-D seismic-inverted model showed higher lateral resolution but poor vertical resolution. The co-kriging model showed favorable resolution both vertically and laterally. The resulting reservoir geology model provided insights into assessing the distribution of pay sands. Since in this area, resistivity is a good indicator of lithology, the study results demonstrate that geostatistical inversion of seismic data to resistivity is useful in predicting sand distribution, and for optimizing future drilling locations.
Two-Phase Helico Axial Turbines
Authors: Charron Yves , Acloque Elise , Stihlé Sylvain 
Published: December 2007

Abstract
Following the development of two phase helico axial pumps in the seventies a R&D program has recently been launched by IFP and DBGP for the development of two phase helico axial turbines. These turbines may be used in many process applications in replacement of let down valves for energy recovery but also to increase the cooling duty or the liquid production. They may also be used in systems including a two phase separator with single phase turbines or valves at its outlets in view of reducing the number of equipment, space and weight. These turbines, suitable for all gas fractions, may find applications in the hydrocarbon upstream field (HP/HT wells, fractured reservoirs, oil stabilisation, electricity production in remote areas) or in the hydrocarbon downstream field (refrigeration cycles, LNG, gas drying, solvent regeneration or hydrotreatment units). This wide potential field of applications requires helico axial turbines to be suitable for a broad range in flow rate, pressure, temperature and gas fraction. This has several consequences on the pump design, particularly, regarding the mass transfer occurring during the pressure let down and the volume change across a turbine or a hydraulic stage. A two phase helico axial turbine prototype will be tested, in single and two phase flows, during the second half of 2003 to confirm the expected hydraulic performance.
Fixed Depth of Investigation Log for LWD Resistivity Tool
Authors: Bittar M. S. , Hu G. , Xiao J. 
Published: December 2007

Abstract
For years, wireline array-induction resistivity data have been processed and displayed at fixed multiple depths of investigation on logs. Modern multi-frequency, multi-spacing logging-while-drilling (LWD) resistivity tools are capable of measuring resistivities at multiple radial depths of investigation. However, since wireline and LWD tools are governed by different tool physics, it is sometimes difficult to compare data obtained by these two devices. Therefore, it is desirable to deliver LWD resistivity data in a manner that is comparable to the presentation of wireline array-induction data.
This paper presents a new approach to process and display LWD data at fixed depths of investigation. This approach starts with a non-linear, iterative deconvolution to simultaneously correct for both relative dip and shoulder-bed effects. Using these corrected logs, the formation resistivity and invaded zone resistivity are determined by an inversion technique that assumes a step-invasion profile. This enables the method to better address the non-linearity of the LWD tool's response. After that, a least-squares curve-fitting technique is used to derive a function that models the relationship between the physical spacing of the transmitter-to-receiver pair and the depth of investigation. Using the same technique, a second function, which models the relationship between the transmitter-to-receiver spacing and the resistivity reading is derived. The first function is utilized to determine a set of fictional spacings that, if used, would result in the desired fixed depths of investigation. These fictional spacings are then used with the second function to calculate resistivity values at the desired depths of investigation, which are chosen to match some of those typically used for wireline array induction tools. The processed data thus obtained provide a meaningful way of comparing array induction and LWD resistivity data.
Field Application of Unconventional Foam Technology: Extension of Liquid CO2 Technology
Authors: Gupta D. V. S. 
Published: December 2007

Abstract
Liquid CO2-based systems have been pumped as fracturing fluids in North America since the early 1980s and liquid CO2/N2 system from 1994. The fluids have been used in more than 1000 wells in a variety of formations having permeability values from 0.1mD to 10 Darcies, depths in excess of 3000 m and bottom-hole temperataure (BHT) from 10 to 110 °C. The chemistry and physics of these fluids are intriguing and have been described before. Several attempts to increase the viscosity of liquid CO2 have been tried with little success. Here, a novel fluid is described that retains all the nondamaging aspects of liquid CO2 but with increased viscosity. This fluid is a foam of nitrogen in liquid CO2. It uses a CO2-soluble foamer that does not damage the formation and can be released into atmosphere without damaging the environment. The fluid does not include any other liquids, such as water, alcohol or hydrocarbons. The foam thus formed follows conventional foam physics (with respect to viscosity increase as a function of internal phase volume, etc.). Due to the limited amount of liquid CO2 used (around 20-25 volume% for a foam of internal quality of 75-80%), multiple jobs can be conducted on a single day making the system more cost-effective than the typical liquid CO2 fracturing system. A summary of the field use for shallow gas applications in Canada is described.
Acid Fracturing of a Gas Carbonate Reservoir: The Impact of Acid Type and Lithology on Fracture Half Length and Width
Authors: Bartko K. M. , Nasr-El-Din H. A. , Rahim Z. , Al-Muntasheri G. A. 
Published: December 2007

Abstract
The Khuff formation is ideally made-up for acid fracturing because of the heterogeneous nature of the formation, which tends to support the created fracture conductivity. Various acid types were used to fracture this tight dolomitized formation including: 28 wt% regular HCl, emulsified acid, and in-situ gelled acid. In addition, several wells were fractured using 15 wt% HCl/9wt% formic gelled acids. However, based on production results and the large database of acid fracture treatments (more than 70 wells); it appears that there is a correlation between the acid type used and the lithology of the formation. An earlier study,1 which briefly examined this phenomenon, indicated that the emulsified acid might be more suited to low permeable zones. These low permeable rocks are predominately made up of limestone.
Typically, changing the acid volumes, placement techniques, or pumping rates, has optimized acid fracture treatments by creating longer and wider fractures. However, we tend to ignore the effect of lithology in carbonate formations because we all believe that the rock interaction with the acid is not as sensitive as in sandstone formations. With this large database of acid fracture treatments, acid rock interactions were investigated to determine the relationship between lithology and acid type.
This work involves correlating the designed treatment to the open-hole logs, core petro-physical data, analysis of hundreds of samples collected following acid fracture treatments, and production results.
Impact of Transient Flow Conditions on Electric Submersible Pumps in Sinusoidal Well Profiles: A Case Study
Authors: Noonan S. G. , Kendrick M. A. , Matthews P. N. , Sebastiao N. , Ayling I. , Wilson B. L. 
Published: December 2007

Abstract
ChevronTexaco has 13 wells producing offshore Africa via electric submersible pumps (ESPs) that experienced problems primarily due to the transient nature of the multiphase inflow through the sinusoidal well profiles. A study completed in 2002 used a transient multiphase simulator to model the sinusoidal sections of each producer and calculate the conditions that the ESPs could see over the life of the well for various drawdown conditions and speeds. This paper will focus on how the results from the simulator were validated and used to reduce operational downtime and improve future ESP completion designs. This paper will also demonstrate how severe sinusoidal well profiles impact production operations.
New Approach for Modeling Progressive Cavity Pumps Performance
Authors: Gamboa Jose , Aurelio Olivet , Sorelys Espin 
Published: December 2007

Abstract
Progressive Cavity Pump (PCP) performance has been traditionally modeled as a composition of Couette flow and Poiseuille flow, represented by pump displacement and internal slip respectively. Pump displacement can be easily calculated from pump components geometry, but calculating internal slip is not a trivial problem. Previous studies have proposed to use Hagen-Poiseuille equation for modeling internal slip flow, assuming a constant interference value. In these studies slippage gap area is not clearly defined, so great results have not been reached.
This study introduces a new approach for modeling single lobe PCP performance. Slip flow is modeled as the result of two components, one of them due to the movement of the rotor and the other one due to the differential pressure between cavities, assuming that slippage gap area depends on the stator material. This assumption is based on the analysis of metallic, elastomer and PTFE stator PCP characteristic curves, obtained from experimental data of previous works.
The existence of a strong relationship between slippage gap area and differential pressure, related to mechanical properties of stator material, is demonstrated. Thus, internal deformation of stator is identified as the main parameter to be understood before predicting PCP performance. For a polymer stator PCP this relationship approximates to a quadratic form, while in a metallic stator PCP a constant gap area can be assumed.
Although the proposed model is not able to fit data for any PCP models, its results agree with the ideas proposed above and documented PCP performance theory. In order to obtain a definitive model, future investigation is needed to improve expressions for calculating friction factor inside the pump and also to define a procedure for obtaining gap area relationships for any type of stator material.
Management of Typhoon: A Subsea, Deepwater Development
Authors: Ring Jasper N. , Bourgeois Christine S. , Howard James , Melillo Allan J. , Neal Scott L. , Smith Steve 
Published: December 2007

Abstract
Typhoon, located in the Green Canyon area of the Gulf of Mexico, is a joint deepwater development between ChevronTexaco (operator) and BHP Billiton. First oil was realized in July 2001, just six years after acquiring the leases. The Typhoon development consists of a mini-tension leg platform (TLP) with 4 subsea wells in approximately 2100' of water. Recently, Boris, a joint project between BHP Billiton (operator), ChevronTexaco, and Noble Energy Partners, was discovered in an adjacent OCS block, and 2 subsea wells were tied back to the TLP. The field consists of several hydrocarbon bearing sands with 60% of the field's proven reserves located within a single reservoir.
Characteristics typical of many deepwater developments such as high flow rates, compartmentalization, reservoir compaction, and asphaltene precipitation are prevalent at Typhoon. As a result, asset management is complex and requires each well to be managed independently. The primary purpose of this paper is to describe how the asset and wells are managed and to heighten the awareness of associated complexities. This will be achieved by providing an overview that includes well and reservoir performances to date, reservoir management processes, and idiosyncrasies associated with operating a deepwater, subsea development in the Gulf of Mexico.
Extended Reach Stimulation with Coiled Tubing: A Case Study
Authors: Patrick Kori , Hornett Mark , Foose Joe 
Published: December 2007

Abstract
Extended reach horizontal wells in Western Canada and around the world are increasing in numbers as operators maximize well production. As the length of the horizontal increases, so does the challenge of open hole stimulation.
Burlington Resources, in association with BJ Services completed what is believed to be the deepest open hole horizontal re-entry with coiled tubing, in the world. This paper reviews stages of planning, design/modelling and operations required to successfully stimulate the Burlington Hinton well with coiled tubing.
The well was completed to a total depth of 21,670 ft with end of tubing at 18,308 ft. The 3,363 ft open hole section was drilled with a 5.875 inch bit. A 1.75 inch tapered coiled tubing string was designed to reach total depth (TD) unassisted by any extended reach bottom hole assembly. Several different factors, including completion and coil size, dogleg severity, buoyancy, friction, fluid type and others affect possible lateral extension into the open hole. Some of these factors can be identified and configured prior to running coiled tubing in hole. Others change during treatment. A computer model, Circa, was used to design the coiled tubing string size and to predict effects of many variables.
Once the process for entering the well was designed, three other methods were contemplated during the operational stage to assist the coiled tubing to bottom. Invert mud was left in the open hole in order to lubricate the coil and reduce frictional drag.A metal to metal friction reducer was on location as a contingency to reduce friction in the system.The coil could be displaced to nitrogen and "floated" in.
Only the first of the above procedures was required to reach TD. A detailed pumping schedule during run in hole was designed to keep the invert mud in hole until reaching TD. It was then removed prior to pumping acid. This paper references some of the fluid compatibility issues associated with pumping water, diesel, and acid when in contact with drilling mud. With appropriate planning, design/modelling and execution, this case study proves that a successful treatment program can be performed on extended reach horizontal wells.
Organisational and Technical Aspects of an Ultra-Reliable Mud-Logging Service Capable of Remote Operation and Control
Authors: Kårtveit S. , Sawaryn S. J. , Jones B. L. , Wahlen M. , Mosness T. L. 
Published: December 2007

Abstract
The development of Baker Hughes onshore operations centre, BEACON was described in the paper SPE78336. A critical component of the concept is the movement of certain services, including mud-logging, from the rig site to shore. Traditional mud-logging systems were designed assuming that the operators could intervene when required, for example to repair or calibrate the sensors. By moving people onshore, this assumption is no longer valid. Further, changes must be made to the work processes, including people competencies and training, to match the new working practices. Experience on BP's Valhall DP operations demonstrated that greater reliability would be required in all aspects of the mud logging service to achieve the reliability goals.
In January 2002, Baker Hughes INTEQ and BP were awarded a grant under the Norwegian Demo2000 program to develop a rig and operator independent ultra-reliable mud logging service capable of remote operation and control from the centre, located in Stavanger. The funding has enabled the issues related to the intimate mixture of people, process and technology to be addressed.
To help address the competency issues, a state-of-the-art mud logging training facility has been created. A new generation of high reliability sensors including an innovative gas trap and hydrogen generation device have been produced. Technicians will be able to maintain and calibrate these from the onshore centre. At the same time, new work processes have been developed to improve business efficiency and HSE. These are small, but critical steps to help shape drilling automation in the future.
The paper contains a description of the system's analysis, including a comparison with the NORSOK standards, which serve as a benchmark. The additional requirements imposed by the need for remote control are also presented.
Integrating Internet Technologies to Achieve Team Synergy and an Improved Operational Efficiency/Work Flow in an Asset Team
Authors: Inyang Ubongabasi I. 
Published: December 2007

Abstract
Complexities and varied areas of expertise in the management of an asset necessitated the adoption of team approach for effective reservoir management. Well-integrated asset team for the management of an asset comprises of petroleum engineers, geologists, facilities & safety engineers, operation personnel and various contracting companies. The group in synergy coordinates the various forms of field developments, operations, reservoir surveillance & data acquisition, well maintenance and workovers. An asset team is faced with an enormous challenge of ensuring that it achieves its goals and synergy between stakeholders, is faced with operational problems. The most critical is communication. This hinders operation and productivity, as all stakeholders are not up-to-date for prompt decisions, job status and rapidly changing well/field conditions. The drive for greater efficiency combined with the ever increasing complexity of today's assets requires an improvement in workflow method.
The latest achievements in Internet technologies call for re-engineering of teamwork methodology. Internet avails an opportunity to improve our work method to create an atmosphere of excellent communication and collaboration that can promote effective team strategies to leverage reduced cycle time, increase participation, share best practices and value creation. This paper intends to illustrate how IP (Internet Protocol) communication can be used to create collaboration, communication and enhance productivity tools. This will establish a central place where every team member and stakeholder across geographic location is kept up-to-date. IP communication utilizes the converged network of integrated voice, data and video to mimic a conference room meeting. The result is immediate access to information that is the key to success where decisions need to be made promptly. The organizational impact of these will be a significant benefit in the areas of improved communication, productivity, enhanced capital, strengthened teamwork across divisions and geographic boundaries, improved processes, efficiency & productivity, work flow along with employee satisfaction, sense of belonging and accomplishment.