bluuebunny/crossref_metadata_2025_split huggingface dataset:
Allocation Process Modeling for Deepwater Production
Authors: Lerma Perla Gonzales , Simonton Chad , Wadle Tim 
Published: December 2007

Abstract
Development costs have risen drastically as producers have ventured into deepwater operations. This increase in investment level has created a case to tieback subsea wells to hub facilities. The various tiebacks which introduce commingled production with different ownership and royalty rates have significantly increased the complexity of the allocation process, i.e. determining individual well production, portion of sales, etc. Thus, a great deal of effort is spent on determining the best approach and most accurate means of analyzing and allocating the production. On an ongoing basis, the management of the allocations can be a significant effort and many companies have developed custom processes. On top of the allocation complexities, companies are now faced with Sarbanes-Oxley compliance requirements.
BP faced these issues in the management of their complex allocation processes in the Gulf of Mexico (GoM). This presentation discusses the process and trials faced in developing a solution that meets all audit and operational requirements. The final solution, rolled out last year, involved the change of business processes within BP, the development of a new application by P2 Energy Solutions and some BP specific processes developed by several third parties. The benefits thus far have been substantial and include the ability to process each facility in a timely, accurate, auditable and reliable manner.
Geomechanics Insight Into Discrepancies of Core to Image Log Discontinuities and Implications for a Lower Cretaceous Carbonate Field
Authors: YiMing Jiang , Chakravorty Sandeep , Marsden J. Robert , Edwards H. Ewart 
Published: December 2007

Abstract
Renewed interest in fractures and faults in a giant carbonate oilfield offshore Abu Dhabi involves such aspects as their origin, nature, orientation, and impact on productivity of Lower Cretaceous hydrocarbon reservoirs. Studies identified a conundrum with respect to core and image log correlation of discontinuities: fractures and faults, seen on electrical image logs, cannot always be discerned as to whether they are of natural or drilling-induced origin. Cross-reference with cores from the same sections allows such discrepancies to be reconciled: in an example case it was observed that a large number of fractures seen on the images were absent in the cores. This paper describes how geomechanical analyses have been used to address factors leading to the development of drilling-induced features in a borehole and to explain why some fractures on the electrical images were also seen in the cores whilst others were not. This method allows differentiation between natural and drilling-induced fractures when core is absent.
The geomechanical analyses involved using various logs to generate single- and multi-well Mechanical Earth Models (MEMs) describing rock stresses and rock mechanical properties. Using uniaxial compressive strengths (UCS), tensile strengths, rock stresses and estimates of cooling in the boreholes by the circulating drilling fluid, it was demonstrated that mud pressures alone were insufficient to cause the observed artificial fractures. However, thermal effects around the borehole were an additional major contributing factor to many of the observed fractures, and consideration of borehole cooling provided a good match between predicted induced fractures and those seen in the image logs and cores.
Such cooling-induced artificial fractures were found to be common in most of the wells where images were available, mainly located within dense zones. Since fractures in these dense zones play an important role in communication between different reservoirs, the ability to differentiate between actual and apparent fractures seen in image logs is of significant benefit to understanding the reservoirs and their interactions.
A New Technique for Cementing Liners During Total Losses and Gas Influx Using a Foamed Cementing System
Authors: Leuranguer C. , DeMestre P. , AlFadhli A. , Xenakis H. 
Published: December 2007

Abstract
Drilling through weak formations with total losses, while concurrently controlling gas influx by pumping water down the annulus, is a situation often encountered in the main Northern Oman carbonate oilfields. Consequently cementing the intermediate liner and aiming to achieve total annular coverage for zonal isolation becomes a challenge.
This paper describes a technique that has permitted the intermediate liner to be set and fully cemented while experiencing drilling fluid losses and formation flows. Using this technique, the liner packer is set before cementing, thus isolating the gas influx and removing the need to pump in the annulus during the cementation. Then by cementing using a foamed spacer and foamed cement in stages, the fluids can be effectively diverted up the annulus across the loss zones resulting in zonal isolation. For better control of the volumes, and to be able to react to a possible early increase in pressure, the inner-string liner method is used. This cement procedure has been employed on several wells and the cement bond log (CBL) results are very encouraging. Prior to employing this method, cement was only evident around the liner shoe joint. With this new method the total liner length has shown cement coverage from 80-100% with the top of cement (TOC) approaching the previous shoe. In addition this technique has resulted in economic gains by eliminating stage tools and annular packers.
The drilling challenges of these fractured wells, the cementing requirements, the design notion of the foamed fluids, the operational execution, and the observed CBL results are all discussed. The value added by using this technique is also demonstrated.
Challenges, Lessons Learned, and Successful Implementations of Multilateral Completion Technology Offshore Abu Dhabi
Authors: Kikuchi Shuichi , Fada'q Abdulla S. 
Published: December 2007

Abstract
ZADCO with the supports from shareholders and the cooperation of ADMA-OPCO has successfully completed the final design of MLC (Multi-Lateral Completion) system for Reservoirs A and B through MLTBS (Multi Lateral Tie Back System) project in a re-entry well, Well T-2 in Upper Zakum field. Well - T2 was re-completed as dual lateral/dual producer from Reservoirs A and B utilizing a RDS (Re-Entry Drilling System) Ver.2 and a DBD (Dual Bore Deflector) with a latch coupling of orientation device in the 7" liner hanger assembly for each lateral access.
According to TAML (Technology Advancement Multi-Lateral) level specification, the final MLC is categorized as TAML Level-4 E-2-PN-D/4-TR-SEP (Level-4, existing well application, two junctions, producer with natural lift, dual completion, tubing re-entry, separated flow). Multi-Lateral liner hanger system, i.e., accommodating a latch coupling in 7" liner hanger assembly to have a certain access to the upper lateral, was the first success application in the world.
The teamwork and integrated approach for the trial planning and implementation as well as lessons learned from a pre- design trial (TAML Level-4 E-2-PN-D/4-TR-SEP using straddle assembly) for Well T-1 completed in year 2000 have led to reaching the final goal of MLC in Well T-2, which provides ZADCO with following reservoir benefits -:
– Independent coiled tubing access to the upper and lower lateral of reservoir A and B through dual completion to perform effective stimulation and reservoir monitoring. – Full bore access to each lateral immediately after pulling out the completion, which is an additional feature to the pre-design of MLC for Well T-1. – Allow conducting selective water shut-off to cope with water breakthrough into the upper cased lateral and extending well life by drilling a secondary lateral from a window joint installed in the upper cased lateral.
Moreover, another MLC trial using a mechanical selective through tubing re-entry equipment has been also successfully implemented in a quadrant multi-lateral well of RL-2 in 2005 after experiencing an operational failure with the similar MLC design tried in Well RL-1 during 2001.
The successful trial implementations have proved that the MLC system will be able to apply for any new/re-entry well for ZADCO reservoirs, provide new methods for reservoir management, and allow creating new completion strategy for ZADCO field development.
This paper will cover MLC strategy created for MLTBS project, lessons learned through the successes and failures of the MLC trials, and additional challenges planned for future.
The Impact of Chloride Contamination From Leaking Heat Exchanger Tubes on Plant Materials of Construction
Authors: El-Roubi E. Y. , Kermani B. , Nasif M. Selim 
Published: December 2007

Abstract
Heat exchangers using sea water for cooling play an important part in the petrochemical processes, but can also cause damage to other components if the tubes fail. Chloride leaks from heat exchangers in the acid gas removal unit of the ADGAS liquified natural gas (LNG) facilities on Das Island, were detected. This leak posed a potential risk of fast rate chloride stress corrosion cracking (Cl−SCC) on stainless steels (300 series) used in the plant. To examine the effects of Cl− contamination, elaborate analysis of process flow diagrams (PFDs), materials of construction and operating cnditions was carried out. For Cl−SCC to take place a combination of environmental, metallurgical and mechanical factors must prevail.
The investigation led to a number of key conclusions which were adopted and which have contributed to maintaining the integrity and safe operation of the plant. A set of corrosion mechanisms was identified in this plant which can affect its integrity. Finally, a risk rating was developed for each operating vessel/condenser tube bundle, which provided a priority list of areas with high to low potential risk.
The Role of Geomechanics at Early Stages of Field Development: A Case Study
Authors: Gomes Jorge S. , Ribeiro Maria , Neghaban Shahin , Dabbour Yousef , Bahmaish Jamal , Zaborowski Georges 
Published: December 2007

Abstract
This paper presents the methodologies and approaches adopted by the Asset Team to integrate geomechanics at the early stages of a field development. The reservoir is a tight carbonate formation, with low structural relief and is offset by major strike-slip faults. The development plan called for a line drive pattern of horizontal producers and injectors (4000 ft open-hole completions), targeting layers with different petrophysical and geomechanical properties. Water-Alternating-Gas (WAG) was selected as the main recovery process. The main concerns at the early stage of field development were the following: 1) What is the best orientation for the horizontal wells ?; 2) Will there be any thermally induced fracturing during injection ?; 3) What would be the role of the existing faults within the development area ?; Would any fault reactivation be expected ?; 4) What would be the impact of joints/faults as permeability enhancements due to pressure and/or temperature gradients. 5) Is there any stress dependency of porosity and permeability ? All these questions were addressed before planning the horizontal wells by conducting a judicious and fit-for-purpose geomechanical study. The aim of this paper is to summarize the geomechanical workflows conducted in the Team prior to the drilling campaign to assess the best orientation for the horizontal wells.
Miscible Gas Injection Piloting and Modeling in a Giant Carbonate Reservoir
Authors: Haajizadeh Masoud , Hafez Hafez H. , Al Hassan Rasheed , AlKatheeri Abdulla Bakheet , Ghozali Mohamed N. , Kenawy Madher 
Published: December 2007

Abstract
The subject reservoir is a heterogeneous carbonate formation in a giant field located in the onshore area of Abu Dhabi. The reservoir can be divided into a higher permeability upper zone and a lower permeability lower zone, with comparable initial oil in place. The reservoir is currently under peripheral water injection. Because of a high contrast in permeability, the injected water has advanced in the upper zone much faster, resulting in watered out wells in this zone. The water movement in the lower zone is by inverse coning from the upper zone.
A gas injection pilot was initiated in 2002 to evaluate the benefit of miscible gas injection as a secondary process in the lower zone and a tertiary process in the water-flooded upper zone. This paper covers the pilot description and the corresponding compositional simulation studies.
A comprehensive pilot monitoring program was designed to acquire key performance data, including, time-lapse saturation logs, PLT, wellhead and bottom-hole pressure, production tests, gas tracers, and well head samples. The compositional simulation studies comprise one-dimensional models for examining the displacement process, a fine-grid pilot model for analyzing and optimizing pilot performance, and a full field model for assessing potential benefits associated with field-scale gas injection options.
The pilot has been in operation for over three years and has met all the initially set objectives. The paper discusses the observation results and compares them with simulation predictions. We show that model predictions satisfactorily match field observations. In particular, both model results and time-lapse saturation logs indicate that the gas, which is injected from a horizontal well in the bottom of the lower zone, quickly moves to the more permeable upper zone, resulting in poor sweep of the lower zone.
The results of the monitoring program are used to optimize the pilot performance and to calibrate the dynamic reservoir simulation model for more reliable predictions.
Uncertainty Analysis of a Giant Oil Field in the Middle East Using Surrogate Reservoir Model
Authors: Mohaghegh Shahab D. , Hafez Hafez , Gaskari Razi , Haajizadeh Masoud , Kenawy Maher 
Published: December 2007

Abstract
Simulation models are routinely used as a powerful tool for reservoir management. The underlying static models are the result of integrated efforts that usually includes the latest geophysical, geological and petrophysical measurements and interpretations. As such, these models carry an inherent degree of uncertainty. Typical uncertainty analysis techniques require many realizations and runs of the reservoir simulation model. In this day and age, as reservoir models are getting larger and more complicated, making hundreds or sometimes thousands of simulation runs can put considerable strain on the resources of an asset team, and most of the times are simply impractical. Analysis of these uncertainties and their effects on well performance using a new and efficient technique is the subject of this paper. The analysis has been performed on a giant oil field in the Middle East using a surrogate reservoir model.
The surrogate reservoir model that runs and provides results in real-time is developed to mimic the capabilities of a full field simulation model that includes one million grid blocks and takes 10 hours to run using a cluster of twelve 3.2 GHz CPUs. In order to effectively demonstrate the robustness of Surrogate Reservoir Models and their capabilities as tools that can be used for uncertainty analysis, one must demonstrate that SRMs are competent in providing reasonably accurate results for multiple realizations of the reservoir being studied. In order to demonstrate such robustness and their predictive capabilities as well as their limitations, this paper will examine the performance of the surrogate reservoir models on different geologic realizations of the static model.
Production Well Testing Optimization Using Multiphase Flow Meters (MPFM)
Authors: Hassan M. Metwalli , Bekkoucha M. , Abukhader M. 
Published: December 2007

Abstract
Production testing using portable Multiphase Flow Meters (MPFM) was implemented in ADCO Field "B" with objectives to quantify the water and gas production, evaluate the performance of slugging/intermittent wells for procurement actions, evaluate the production test data measured by the conventional test separators and improve the testing duration and strategy. The program included in addition a set of elements to qualify the multiphase meters results before use and considered parallel testing with conventional separators to allow fair comparison of results.
More than 50 wells were tested during this campaign. All these wells were selected carefully to represent anomalies that need to be investigated for possible proactive actions. Some of these wells were tested more than once to qualify and validate the production test results by the MPFM. Production test results were carefully analized and compared with the results of test separators for fair evaluation and interpretation of well's behaviour. The comparison indicated that the multiphase meter results were relevant and accurate.
In conclusions the water cut measured by MPFM was almost three times more than those measured by test separators. This ratio is matched well with the actual field water volumes. The GOR measurements were varying from one well to another but majority of wells showed more gas production by the phase tester compared with test separators specially for the low potential, unsteady wells. In terms of oil production rate, the difference between the phase testers and test separators was marginal in high potential wells and between 20-40% higher by MPFM in low potential wells. These findings helped in optimizing reconciliation and allocation of the water and gas production. In addition to the above findings, phase testers helped in reservoir management decisions and optimization of testing duration and frequancy per well, testing remote wells, slugging/intermittent wells due to system back pressure, testing wells located on platforms not equipped with testing facilities, easy mobility of the phase meters between different locations, replacement of portable test separators and cost optimization.
This paper presents the experience gained using a mobile multiphase well testing unit for production testing. The challenges presented by the nature of these operations and the requirements for successful well tests are reviewed. The importance of well testing experience and multiphase flow metering expertise is highlighted. The paper also explains the unique benefits of the multiphase well test data in identifying and evaluating various well performance anomalies and how the measurements are used to monitor well production over time.
The Application of Air and Air/Foam Drilling Technology in Tabnak Gas Field, Southern Iran
Authors: Chen Guang , Chen Xingyuan , Liu Desheng , Cheng Xiaonian , Liu Chuansheng , Wang Dekun 
Published: December 2007

Abstract
Tabnak gas field is located in the Fars province, Southern Iran. Severe lost circulation problem were encountered while drilling the long interval of large size hole in the highly fractured and porous carbonate formations. To resolve the severe lost circulation problem, Air and air/foam drilling technology was chosen as a main means to drill through the top intervals and an air/foam drilling program was worked out. The field application proved that air and air/foam drilling could resolve the severe lost circulation problem in the highly fractured and porous carbonate formations with very low formation pressure and speed up the penetration rate significantly. The drilling cost also reduced dramatically.
Installation of Online Vessel Desander Manifolds
Authors: Jasmani M. S. , Geronimo E. C. , Chan L. 
Published: December 2007

Abstract
Sand production in the brown field is a common phenomenon. If left uncontrolled, sand can erode the line pipes, valves, instruments and ultimately causes unplanned production shutdown. Even if the sand production rate is relatively low, sand can accumulate inside the production separators after a period of production. This sand build-up is reducing vessel volume for effective separation of oil, gas and water.
Dulang-B Platform, which is located at South China Sea and operated by Petronas Carigali Sdn Bhd (PCSB), has recorded severe sand accumulation on its production separators as observed during vessel inspection. This resulted in unnecessary production downtime to allow for cleaning of the vessel and removal of sand.
To mitigate the problem, two units of Online Vessel Desander (OVD) manifolds were installed inside one of the HP Production Separator of the platform on trial basis. Each manifold consists of a series of pipe work connected to the desander devices. The device uses hydrocyclone principle to elevate and transport sand from the base of the vessel out to a filter tank without the need to isolate the process stream. This pilot installation of the manifolds was the first in PCSB and Malaysia.
Over a month period, a total of 809 litres of sand have been removed from the separator vessel with no production downtime. Operations personnel reported improvements on level interface of the separator and less erosion on the downstream equipment, particularly level control valves. The annual shutdown previously required for sand cleaning was also eliminated resulting in monetary savings.
Thus, the OVD manifolds are an effective technology to replace conventional sand jetting for sand removal from production separators.
Assisted Interpretation of Fiber-Optic Data for Smart-Well Completions
Authors: Lee Jim H. 
Published: December 2007

Abstract
New methods have been advanced to process, manipulate, and utilize real-time data from permanent downhole monitoring (PDM) systems such as fiber optic (F-O) pressure, temperature, and flow sensors. These interpretative methods are centered upon detailed computational fluid dynamics (CFD) simulations of the wellbore and surrounding near-wellbore region. In addition to facilitating the solution of geometrically complex flow dependencies, the CFD approach accounts for the highly coupled chemical physics inherent in multi-phase systems, particularly gas compressibility effects that impact wellbore hydraulics and heat transfer which, in turn, govern the flow, pressure, and thermal profiles in the wellbore. In the near-wellbore region, true reservoir permeabilities and porosities are honored and used to populate the CFD model. By running the model for different anticipated production scenarios, a series of production "type curve" analogues are generated that can be used to "predict" the time-dependent flow, pressure, and thermal profiles recorded by a PDM, thereby assisting interpretation of the data.