bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful installation of Straddle With Inflow Control Device To Restrict Gas Influx, A Case History From The Heidrun Field
Authors: Nielsen Marianne Gudmundseth , Auflem Inge Harald , Svela Per Einar , Porturas Francisco 
Published: July 2010

Abstract
The Heidrun field is approaching late life production and several wells have increasing gas oil ratio caused by gas break through. Likely gas inflow is through high permeability streaks or gas cap being drawn into the wells. The Heidrun processing facility is limited on gas processing capacity and hence wells are closed in when the gas oil ratio is too high.
The candidate well was chosen based on results from a production log run in 2008 showing high gas influx in the top screen sections. Interpretation was uncertain as to whether there was only gas or if oil also was coming from the interval, so to completely straddle it off was not a desired option. In order to reduce the gas influx, but maintain some oil production from the dedicated interval, it was decided to install a straddle with inflow control devices (ICD). This way a limitation was imposed on the drawdown of the interval, but the interval would still contribute. The results from the operation exceeded our expectations by far and the asset is now looking for other candidate wells.
This paper describes the method used to determine the size and number of the nozzles in the inflow control device, the length of straddle and technology used to install it. Further it will show the results of the operation until now and potential use of this technology in old and new wells on the field.
Successful Through-Tubing Gravel Pack Unlocks Production in Mature Fields Offshore Brunei
Authors: Shaikh Karim , Adesegha Rotimi , Talib Norliny 
Published: July 2010

Abstract
Sand production remains one of the key risks to maintaining field production rates and maximizing ultimate recovery from mature fields offshore Brunei. Due to the operational challenges and the HSE risks resulting from sand production in the surface facilities, sand producing wells are shut-in prematurely, locking-in well production and remaining hydrocarbons. Very fine, poorly sorted formation sands and uncertainty in general about formation sand particle size distribution leads to a challenge in designing robust downhole sand control completions. Sometimes we get it wrong resulting in the failure of the original sand control completion.
Low cost options to remediate sand production through the deployment of wireline conveyed thru-tubing standalone screens are typically not reliable in this environment and often considered as a last resort option. In addition most of the existing wells are old, have well integrity problems and completed with small 3-1/2" tubing that limit the application of mechanical thru-tubing options. Expensive rig interventions to workover or redrill sanded out wells are typically not justified by the low remaining reserves.
To overcome these challenges Brunei Shell Petroleum embarked on an effort to identify and field test a viable rig-less remedial sand control solution for unlocking production and maximising recovery from existing wells.
This paper documents the work done to select the right technology and the right well candidates for a field trial, the design and planning effort that resulted in the first successful application of a Thru-Tubing Gravel Pack (TTGP) in the NW Borneo region.
A well previously producing sand has now been producing sand free for about a year. In addition the paper provides valuable learnings to those wishing to deploy thru-tubing gravel packing technology in existing wells.
A Successful Application of Near-Wellbore Stimulation Using Fluidic-Oscillation Technique in North Africa Oil Field
Authors: Kritsanaphak Kritsana , Tirichine Salah , Kammourieh Muhammad 
Published: July 2010

Abstract
Near-wellbore damage can cause severe reduction in effective permeability and production. A typical solution for near-wellbore damage removal involves wellbore cleanout and squeezing the treatment fluids into the formation through perforation with a conventional jetting-nozzle run on coiled tubing. However, there are numerous old wells in North Africa oil fields that have been completed with a slotted or preperforated liner and require an effective near-wellbore stimulation to remove the damage and restore the near-wellbore permeability and production.
A fluid-oscillation technique created by a fluidic-oscillator (FO) tool was applied successfully in conjunction with stimulation treatments, such as matrix acidizing, salt, and asphaltene treatment. The results from using this tool instead of the conventional jetting tool were significant; the post-stimulation production improved over previous stimulation gains when performed on the same wells. Recently, the fluid-oscillation technique was also applied effectively for near-wellbore stimulation treatments in horizontal wells without requiring matrix squeezing. Results from using this technique have been promising and have simplified the near-wellbore damage treatments. Several wells in this field were treated using this near-wellbore stimulation treatment, resulting in significant production gains. Using the matrix and near-wellbore stimulation in conjunction with the FO tool has become the preferred method to enhance the effectiveness of treatments.
The FO tool creates pressure waves within the wellbore and formation fluids that break up near-wellbore damage to restore and enhance the permeability of the near-wellbore area. As the damage is removed and the original permeability is restored, the pressure waves can penetrate deeper into the formation matrix for more complete damage removal. The direct comparative results from using conventional jetting nozzles and FO tools for several wells in a North Africa oil field are quite evident and are presented in this paper. This technique should help other operators enhance the effectiveness of near-wellbore treatments to achieve similar benefits.
Cementing in HPHT Gas Environment Using a Novel Flexible And Expandable Cement Technology To Withstand Pressure And Temperature Cycles
Authors: Thuwaini J. A.-I. , Emad M. , Ekpe J. , Jaffery M. , Ong D. , Bermudez R. , Taoutaou S. , Ahmad B. 
Published: July 2010

Abstract
Long-term zonal isolation is an important factor to consider while designing cement slurries for deep high-pressure, high-temperature (HPHT) gas wells. Conventional heavyweight cement systems used in the past have often had to sacrifice set cement mechanical properties, such as compressive strength, permeability, and porosity, to provide a stable, mixable, and pumpable slurry design.
Changes in downhole conditions in terms of temperature and pressure can induce sufficient stresses to destroy the integrity of the cement sheath, causing long-term gas migration and sustained annular pressure. Hence, the set cement mechanical properties have to be carefully designed in order to withstand the downhole stresses, especially the ones generated from well testing.
A novel flexible and expanding cement system was chosen for the eighth well of project in Saudi Arabia.
Integration of Static and Dynamic Data to Investigate Interwell Communication: The Case of Module II of Espadarte Field, Campos Basin, Brazil
Authors: da Motta Pires Paulo Roberto , de Lira Eloisa Moreira , Costa Aline Cortizo , de Souza Fabio Carvalho , Benjamin Edivar Narcizo , dos Santos Peter Monteiro 
Published: July 2010

Abstract
This paper describes the investigation of interwell communication in the Module II of Espadarte field, located in the Campos Basin, offshore Brazil. The field started production in January 2007, seven months before water injection. All active wells are equipped with permanent downhole gauges (PDG) to continuously record flowing pressure and temperature.
As history data became available, PDG bottom-hole pressure was extensively analyzed to infer reservoir properties, estimate its pressure and determine well parameters, such as effective permeabilities, skin, and productivity or injectivity indexes. A routine of injector fall-off tests was implemented. The results obtained were combined with the interpretation of producer pressure build-ups after platform shutdowns. Additionally, in order to evaluate their level of connectivity, the reflect of topside events affecting the injectors was also investigated on the flowing pressure of the producers.
A number of seismic attributes was used to correlate reservoir properties with the degree of connectivity between wells inferred from production behavior. Seismic data was processed through the training of an unsupervised neural network identifying clusters or regions of different seismic properties within the reservoir. A material balance model with interference was developed to represent and evaluate the degree of compartmentalization suggested by bottom-hole pressure analysis and seismic interpretation.
All this information together made possible the identification of regions with poor and good communication between injectors and producers. Conclusions have given support to the history matching of a numerical simulator as well as the optimization of water injection rates. This work also highlights the importance of integration of static and dynamic data, represented by seismic attributes and PDG measurements, respectively, to the monitoring of well and reservoir performance.
Deep Tight Gas Zonal Isolation Solution with Novel Flexible and Expandable Cement Technology
Authors: Thuwaini J. A-l , Emad M. , Belousov Y. , Ekpe J. , Taoutaou Salim , Jaffery Maimoon Fayyaz , Ahmad Bilal , Elatrache Bassam 
Published: July 2010

Abstract
The long term zonal isolation is an important factor to be considered while designing cement slurries for deep High Pressure, High Temperature (HPHT) gas well. Conventional heavy weight cement systems which have been used in the past have often had to sacrifice the set cement mechanical properties such as compressive strength, permeability, and porosity, to provide a slurry design which is stable, mixable and pumpable.
Changes in downhole conditions in terms of temperature and pressure can induce sufficient stresses to destroy the integrity of the cement sheath which will cause long term gas migration and sustained annular pressure. Hence, the set cement mechanical properties have to be carefully designed in order to withstand the downhole stresses especially the ones generated during the well testing and fracturing treatments.
This paper will discuss the selection and the Novel Flexible and Expanding cement system and details one well case history of nine wells which is part of the upstream agreement with Saudi.
Condensate Banking Phenomenon Evaluation in Heterogeneous Low Permeability Reservoirs
Authors: Giamminonni D. , Fanello G. , Kfoury M. , Colombo I. , Bonzani A. 
Published: July 2010

Abstract
In low and tight gas formations, condensate banking will form in shortly time after production start-up due to pressure drop below the saturation pressure. Mobility reduction near wellbore area will affect well productivity. The prediction of gas condensate wells production will strongly depend on oil banking evaluation and modeling.
A benchmark radial fine well model has been built using constant petrophysical properties per each layer. Several coarse Cartesian grids have been considered to evaluate discrepancies in terms of production and flowing pressure with respect to the benchmark grid. For a coarser Cartesian grid, it has been deduced that Generalized Pseudo-Pressure (GPP) is a key parameter to avoid well performance over-estimation. An alternative solution consists in defining a local grid refinement (LGR) near wellbore to honour the benchmark solution without using GPP.
In this case study a LGR technique has been used to incorporate future hydraulic fractures for the wells development. A real application case has been considered to extend lessons learned from benchmark to field scale. A proper geological model has been built using a sedimentological model as driver for petrophysical properties distribution.
Two DST have been considered to analyze condensate banking phenomena evaluation in a low and medium permeability matrix. To this purpose, three analytical models have been considered. Thus, to validate a representative analytical model a numeric simulation has been performed. Based on the obtained results, it can be affirmed that the radial composite is the most appropriate analytical model reproducing the phenomenon of gas mobility reduction in the nearest wellbore region.
A New Water-absorbent Resin for Lost Circulation Control
Authors: Lai Xiaolin , Guo Jianhua , Zhou Yaxian , Jiang Xueqing , Li Xudong , Wang Zhonghua 
Published: July 2010

Abstract
Eliminating or controlling lost circulation during drilling or cement operations is a costly and time-consuming process. Water-absorbent resins play an important role in mud loss control for their deformability and water-absorbable and expandable properties. This paper developed a new kind of water-absorbent resin, Double Network Water-absorbent Resin(DNWR), which could be used in deep well or ultra deep well to solve loss problems.
The most difference between DNWR and traditional water-absorbent resins is that DNWR has excellent mechenical properties and good thermal stability; it can be used at the temperature of 150°C for more than 30 days, while the later only could be used below 120°C. The properties and the mechanism of controlling mud loss of DNWR were discussed, after being pumped and squeezed into the formation fracture, DNWR could expand 5–10 times of its original volume, adsorb on the fracture surface, and form a compact sealing layer. Laboratory tests had shown the effectiveness of DNWR in plugging different borehole sizes with a high temperature. The efficiency of this system was enhanced in the laboratory when combined with other inorganic bridge materials which have good thermal stability and optimized particle size distribution.
Improved Permeability Prediction in Heterogeneous Carbonate Formations
Authors: Burrowes Arden , Moss Adam , Sirju Clive , Pritchard Tim 
Published: July 2010

ABSTRACT
Understanding the dominant pore structures is a crucial tool in modelling carbonate reservoirs. Information on pore structure can be obtained through image logs or core data. In situations where there is limited available data such as core analysis, other data sources such as rock cuttings should be explored. Once the pore structure is understood, the appropriate model can be chosen. It has been found that a modified approach to traditional Nuclear Magnetic Resonance (NMR) techniques gives improved accuracy where conventional methods fail. This method results in a better understanding of reservoir behaviour, which should ultimately result in increased hydrocarbon recovery.
For this paper, samples from a highly heterogeneous carbonate database of petrophysical properties are reviewed against established classification methods, such as the Lucia, Choquette and Pray, and newer methods such as the Lonoy classification. Mercury Injection Capillary Pressure (MICP) and NMR data are used to investigate and relate rock types and their dominant pore structures, to measured pore throat and body sizes. Common permeability models are reviewed for each classification and the suitability of each model is assessed and ranked using Pearson's coefficient and a power function. This case study demonstrates where traditional NMR porosity-permeability models are successful and where they are not, and proposes a modified approach to modelling the rock types where traditional methods fail. The practicality of identifying these rock types from logs is discussed and recommendations are made for evaluating heterogeneous carbonate formations. This approach can be applied to heterogeneous carbonate formations where NMR logging runs have been conducted and core samples have been obtained.
Enabling Materials and Corrosion Technologies for Gas Developments
Authors: Wright Eric J. 
Published: July 2010

Abstract
Effective technology application is increasingly important as hydrocarbon resources become more difficult to locate and produce. This approach is illustrated by recent developments in materials and corrosion technology that are applicable throughout the gas production chain. A large proportion of upstream project expenditures are related either to direct procurement costs or fabrication. A wide range of materials is used, although the bulk is represented by specific grades of carbon steel. In addition, the evolving nature of the materials challenges requires the development and specification of materials with improved properties to meet continually higher performance demands.
Qualification testing of these materials, including testing in accurately simulated service conditions coupled with effective specifications and quality assurance is key to achieving the required integrity. Technology developments discussed include: corrosion control to enable full well stream, subsea wet gas pipelines, higher-strength steel for gas transmission pipelines and cryogenic line pipe using nickel-based alloys for subsea LNG transfer. The examples described highlight the important contribution of materials and corrosion technologies to enabling high integrity, cost effective gas field developments.
Evaluation and Qualification of Materials for Subsea Insulation Systems
Authors: Ruschau Gregory R. , Rogers Robert H. , Woodley Sophia A. , Wright Eric J. 
Published: July 2010

Abstract
Thermally insulated subsea production systems are becoming more common in deepwater completions for hydrate or wax control. Premature failures of the insulation materials for these systems have had signification operational impact. Syntactic foams or solid polymer insulation are currently the industry standard for subsea completion equipment. The types of insulation commonly used, their failure modes, and improved methods for selecting and qualifying these insulation systems are presented. For deepwater application, so-called "wet" insulation systems are preferred, because the insulation can be molded directly around the equipment without the need for an outer protective jacket. The insulation is exposed directly to the seawater on the outer surface, with the inner surface exposed to the high temperature operation. The critical parameters in design are the thermal conductivity, insulation thickness, and specific heat capacity. The material parameters of primary concern are resistance to degradation by seawater, high-temperature stability, and physical durability for both deployment and long-term service.
Systematic Elimination and Mitigation of Process Hazards in Project Design
Authors: Kenefake Daryl A. , King Joseph , Victory Donald 
Published: July 2010

Abstract
This paper will describe ExxonMobil Development Company's management system that allows for recognition, evaluation, elimination and/or mitigation of process hazards in upstream facility design. ExxonMobil has a rigorously applied system of design processes and tools through the life-cycle of major projects including concept selection, preliminary design, detailed design, construction and ultimately the operation of the facility. Application of these tools and processes has enabled safe and efficient operations and project execution. Discipline and commitment to "Nobody Gets Hurt" in the design phase of a project leads to facilities that can support safe operations through decades of operations.
Scaling Issues through Quantitative Analysis between Reservoir Simulation
Authors: Avansi G. D. , de Souza R. M. , Schiozer D. J. 
Published: July 2010

Abstract
Time-lapse seismic has been providing valuable information on identifying fluid movements, to locate bypassed oil and well placement optimization to reduce uncertainties in reservoir development and production management. Nevertheless, most of these are made through a qualitative approach, which limits seismic data integration in reservoir simulation studies due to different scales. In order to overcome this and develop new data integration techniques, many studies involving these processes have the assumption that both frameworks are in the same scale. Nonetheless, the quantification of the lost information in the scaling procedures needs to be evaluated and quantitative seismic data integration into the simulator should improve the mitigation of these problems improving the knowledge about the representativeness of the scaled data.
In this context, it is presented a technique regarding to scale issues relating time-lapse seismic data, geological and simulation models aiming to quantify the information lost due to the scaling problems.
This paper describes a methodology involving seismic attributes and reservoir simulation. Saturation and pressure trends derived from acoustic impedance behavior, which were obtained from seismic data. The lost information due to scaling procedures is evaluated through comparison between flux model properties and seismic attributes, at each respective framework, for estimating the best step to do it. This technique allowed the reliability improvement of the reservoir parameters from seismic attributes regarding to the lost information due to scaling procedures.
It has been shown that it is possible to improve the model and results reliability through a quantitative analysis involving scaling procedures between 4D seismic data and reservoir simulation integrated studies.
As main contributions of this technique are the integration procedures regarding to scaling issues between reservoir simulation models and time-lapse seismic information.
Relative Permeability Estimation from Displacement Experiments Using EnKF Method
Authors: Li Heng , Yang Daoyong , Arhuoma Mohamed 
Published: July 2010

Abstract
The relative permeability is a crucial parameter for accurately evaluating reservoir performance. Two-phase relative permeability curves are normally obtained by either directly or indirectly interpreting the displacement experiment data. As for the direct interpretation, the core samples are assumed to be homogeneous, while the capillary forces are normally neglected. Although the indirect interpreting approach is able to take heterogeneity of the core sample into account, calculating the derivatives of the objective functions through the graphical or numerical methods is prone to considerable errors. In this paper, a new method is developed to calculate the absolute and relative permeability from unsteady-state, two-phase immiscible displacement experiments. The permeability data is determined by history matching the experimentally observed pressure drop, production data and water saturation profiles via the ensemble Kalman filter (EnKF) algorithm. The power-law model is utilized to represent the relative permeability. Both the absolute and relative permeability are calculated simultaneously by assimilating the observed data. The newly developed method is validated using a numerical coreflooding experiment. It has been found that estimations of absolute and relative permeability are improved progressively as more observation data are assimilated. In addition, this method is convenient to be implemented as the derivative of the objective function is not required.