bluuebunny/crossref_metadata_2025_split huggingface dataset:
Charge and Structural Timing in Relation to Hydrocarbon Prospectivity for Paleozoic Reservoirs in Abu Dhabi
Authors: Alsenani Haitham Saleh , Taher Ahmed , Alzaabi Mohammed Rashed , Stone Gary C. , McAllister Niall 
Published: November 2008

Abstract
Structural timing in relation to hydrocarbon charge timing has a significant impact on hydrocarbon prospectivity for Khuff and pre-Khuff reservoirs in Abu Dhabi. Maturation of Silurian source rocks began more than 150 million years ago and continues on until today in some parts of Abu Dhabi. A mix of structural growth histories is also observed with some very old structures pre-dating source rock maturation and other very young structures related both to emplacement of the Semail Ophiolites and Zagros uplift. Some of these young structures are located in areas where charge had already finished before the structure formed. Comparing the growth history of each individual structure to the Silurian source rock maturation history at each structure location can explain much of the observed Paleozoic gas distribution that has been observed by exploration drilling. This study investigates the impact of growth timing on the presence of hydrocarbons. It is believed that the use of this analysis substantially increases the confidence in assessing prospect risk ahead of drilling.
In this paper, we reflect on our efforts to undertake comprehensive investigations of the geology of the region. This discussion will cover the methodology which is used to perform the analyses of the growth history. Measuring the growth from seismic sections and from depth contour maps were the two basic methodologies applied.
The interpreted growth histories are compared to the tectonic history of the basin. Basin modeling to understand the timing of source maturation was a separate study, but the results of that work will be shown and the growth history will be compared to the charge history. Examples from Abu Dhabi fields are provided in this study to illustrate our concepts.
Using a Digital Plant Architecture to Prevent Abnormal Situations
Authors: Dennant Andrew 
Published: November 2008

Abstract
The wealth of data available from intelligent field instruments frequently goes unused. This is a waste of the investment in smart devices and, more importantly, does not allow the operator to optimise the performance of the asset. In the worst case it does not allow the user to prevent an abnormal situation (i.e. an emergency). This paper will explore, through concept and case study, how plant performance can be optimised and abnormal situations prevented through the use of intelligent alarm and alert routing.
Using Closed Loop Adaptive Control to Optimise Plant Operations
Authors: Dennant Andrew 
Published: November 2008

Abstract
Studies show that over two thirds of all control loops are poorly tuned or in the wrong mode (e.g. Manual instead of Automatic). Modern control system technology can not only identify poorly-performing loops but also identify the root cause of the problem. In many cases this is poorly-maintained field equipment, such as a badly-maintained valve. Early identification of such a field problem will allow maintenance to fix the problem in a timely way, improving the profitability and throughput of the plant and allowing the loop to be put back into Auto. In many cases the field equipment is operating perfectly, but the loop is poorly tuned. This may be for a number of reasons; the most common are that the loop parameters have not been changed since the plant was commissioned and that different tuning parameters are required in different modes of plant operation. The ultimate goal of loop tuners is the ability to automatically tune all loops in real time all the time, matching the tuning parameters to the process conditions. This presentation will show how this can be easily achieved using modern automation technology.
An Innovative Approach in Tracking Injected Water Front in Carbonate Reservoir off Shore Abu Dhabi
Authors: Amer M. M. , Al-Farisi O. , Hiraiwa T. , Attia M. , Al-Habshi A. , Madjidi A. 
Published: November 2008

Abstract
For pressure maintenance purpose peripheral wells have been used to inject sea water into a carbonate reservoir offshore Abu Dhabi. The injected water preferentially follows the path of the of higher permeability zones, since injection is done into formation water below oil water contact. Though the sea water front movement in the reservoir has been estimated indirectly via numerical reservoir simulator, successes of direct methods have been limited by the injection volume and environmental effects.
Direct spatial measurement of the injected sea water front within the reservoir is important to evaluate the efficiency of pressure maintenance by peripheral water injection, also considered an important step in tuning simulator parameters, and optimizing the Field Development Plan (FDP).
Although there is strong water salinity contrast between the injected and original reservoir water in this field, resistivity-based methods can be affected by variations in the reservoir rock cementation factor, while cased hole logs can be affected by environmental effects such as hydrochloric acid effect commonly seen in carbonate reservoirs after stimulation.
This technique that utilizes open hole Pulsed Neutron Sigma measurement of Logging While Drilling (LWD) enables petrophysicists to distinguish and determine injected water separately from formation water, independent of Archie-based resistivity method. Also this technique provides a new methodology to calculate cementation factor (m). Successful application of this technique in an offshore Abu Dhabi carbonate reservoir is presented here.
New Methodology for Optimized Field Development Plan, Why Do We Need To Introduce Dynamic Rock Typing "Case Study for Simulation Model Improved Accuracy and Reliability"
Authors: Al-Jenaibi Faisal , Hammadi Khaled , Salameh Lutfi 
Published: November 2008

Abstract
The initial hydrocarbon (Oil and Gas) in-place represents the asset volume of ADNOC that is required estimation at high accuracy level with minimum uncertainties to avoid any future risks with fields' development plans. Moreover, accurate estimation of the reserves that can be produced during the field life cycle is critical as it is directly impact the CAPEX and OPEX of different field development phases.
Fields developments are usually selected based on the techno-economic evaluations of the outcome from the full field simulation studies using representative models. Accordingly, management decision for fields' development is totally dependant on the accuracy of the used simulation models.
Worldwide, there are many simulation models successfully demonstrating good history match profiles, nevertheless, several of these models are utilizing unsupported parameters, such as representative capillary pressure and relative permeability curves. In addition to the adverse impact on the predictive reliability, massive convergences problems that are encountered and participating in slowdown the models performance and decreasing accuracy. Subsequently, incorrect Long Term Development Plans "LTDP's" profiles will be generated.
Therefore, in order to ensure achieving more representative asset volume estimates, a new procedure has been setup, established and successfully validated through different fields. The main objectives of the new procedure are to enhance model initialization with minimum gap in terms of hydrocarbon-in-place between the static and the dynamic models below the range of 1.0 %, to achieve more accuracy of the expected movable oil and gas with respect to water flooding (Current Development Plan) and future Gas/WAG flooding (LTDP), to eliminate high risk of assessment of modeling the actual gas/water breakthrough timing, recovery factor, sweep efficiency and fields measured matching parameters, and to cut down potential risks of under/over estimating the water/gas influx fronts in the reservoir.
Quality match is essential in order to prevent utilization of non-measured parameters such as irreducible water saturation (Swc's), also to eliminate utilization of unproven permeability multipliers. Moreover introducing a new capillary pressures (Pc) designing concept will contribute in reducing convergences problems as well as providing more consistent dynamic model setup (dynamic model rock typing).
Based on the results from several simulation studies which were introduced to the new procedure framework, the new procedure managed to demonstrate its capability to design the most reliable capillary pressure profiles. These profiles are essential for simulation models to ensure quality match of lateral and vertical oil and gas distribution in the field which represents the most extremely improvement match achieved when compared with other used method.
Large Hole LWD Compressional Sonic, New Age of High Quality Seismograms in Offshore Abu Dhabi, U.A.E.
Authors: Mercado Gary , Al Farisi Omar , Boyd Douglas 
Published: November 2008

Abstract
Generating a full section synthetic seismogram requires compressional sonic and density logging of the entire wellbore from TD to surface. Offshore Abu Dhabi, this is often difficult to achieve in the shallowest portion of the hole given the large 17.5" borehole size, possible formation collapse resulting in stuck tool condition, and uncontrolled free flowing water zones. Attempts to acquire sonic data through 13 3/8" casing met with mixed results while density logging was considered not an option. Acquiring logging while drilling (LWD) sonic data offers an alternative to wireline acquisition less restricted by adverse borehole conditions.
Uncertain whether LWD or wireline provides the best quality sonic data in a large diameter hole and accepting the risk of lost in hole occurrence, both types of tools were consecutively run followed by wireline density in a 17.5" diameter hole. Formation characteristics varied from clean high porosity limestones and dolomites, to tight anhydrites and shaly limestones. Compression travel times ranged from 55 usec/ft to 155 usec/ft.
A comparison between wireline and LWD sonic logs in a large diameter hole is presented. Sonic data quality, signal coherence and operating environments are reviewed and compared. The technical evaluation shows LWD sonic technology can replace wireline sonic in large holes when hole stability is an issue. However, neither tool provides high quality data under all conditions encountered.
AVO Application in a Carbonate Offshore Oil Field, U.A.E.
Authors: Ikawa Hidemasa , Mercado Gary , Smith Adrian 
Published: November 2008

Abstract
Amplitude Variation with Offset (AVO) is a well known technique as a direct hydro-carbon indicator in clastic gas fields. Carbonate reservoirs usually have a more rigid rock framework making them more difficult to see the changes in elastic parameters based on differing types of fluid saturation. An AVO Pilot Study has been conducted in 2007 to investigate the ability to detect fluid fronts in a producing Lower Cretaceous carbonate oil field, using pre-stack seismic data acquired in 2001. Assessing the position of injected water is a critical factor for future in-fill well location optimization and provides additional support for reservoir fluid movement prediction when coupled with reservoir surveillance and simulation data. The study was conducted in a small pilot area that includes a recently drilled well, where necessary data were available for a modeling. The modeling study was performed utilizing log data to assess the degree of seismic change due to fluid substitution based on Biot-Gassmann equation and synthetics have been generated to compare with actual seismic response. In addition to the conventional AVO technique, other techniques have also been tested such as Elastic Impedance and simultaneous AVO inversion followed by Lambda Rho / Mu Rho(LMR) transforms.
The results of the pilot study were validated with the known well fluid status in the pilot area. Mapping of the different water-oil-gas fluid response using the LMR technique shows a reasonably good agreement with currently known well saturations. It is, however, difficult to discriminate reservoir sub-layer water-cut percentages due to data resolution limitations. Generally, the results of the analysis indicate potential to identify hydrocarbon to water fluid contents, with the above constraints.
Managing Mature Indian Offshore Fields – A Case History
Authors: Mitra N. K. , Kumar Adesh 
Published: November 2008

Abstract
Mumbai High, Neelam and Heera fields, located in Western Offshore of India, are 20–30 years old and matured. Multi disciplinary approach in utilizing modern technology in every step of a well from planning to execution has been adopted in brown field development of these mature fields, Static and dynamic model building with state of art technology has been undertaken to bring out the subsurface picture more vividly. Technology has helped in drilling of ERD wells to far of places from existing platforms in complex subsurface architecture. Well placement technology with online monitoring at base (Virtual Reality Center) has improved proper well steering though thin sweet zones. In area of well completion also higher level multilateral technology has been adopted to monitor and control individual reservoir performance.
Typically, redevelopment project implemented in Mumbai High during 2000–2007 will increase recovery by 4% from 28% by 2030. About 200 wells have been completed in last 5 years. Similar project is under implementation in Heera field and envisages increase in recovery by 3.4%. In last 3 years about 91 wells in Neelam and Heera fields have been completed with latest technology.
Future initiatives are: –application of intelligent wells and smart platforms (3 Nos. of smart well platforms i.e. 1 in Mumbai High and 2 in Heera field installed),–challenge in produced water handling (plans are in vogue for processing capacity enhancement, application of swellable elastomer to reduce water inflow whilst increasing oil production) from high water-cut wells,–application of micro fracture simulation to assess the effects of water injection (FMI Logging).–Enhanced Oil Recovery (EOR) pilot to target residual hydrocarbons for increasing recovery.
The present paper describes in detail about the management of these matured fields to achieve higher recovery and future initiatives.
Challenges in Highly Sour Gas Environment Containing Elemental Sulphur
Authors: Girgis Magdy 
Published: November 2008

Abstract
BACKGROUND
To compete with more conventionally produced gas, wet sour gas is transported from the well head to the gas sweetening units in carbon steel pipelines. Sour gas corrosion can lead to pipeline pinhole leaks which pose hazardous consequences to people, wild life and pollution to the environment. Corrosion is usually controlled through chemical inhibition in combination with frequent batching and pigging programs.
In the presence of elemental sulphur corrosion rate can exceed 30 mm/y. Most of the mitigation methods designed to manage and maintain the integrity of carbon steel downhole tubing and pipelines present in itself some of the toughest technical challenges.
This paper outlines specific corrosion challenges related to the use of sulphur solvents; frequent pigging and inspection programs; corrosion monitoring, the use of lined carbon steel materials and some case histories. The paper also addresses the challenges associated with well acidizing on sulphur corrosion in surface and subsurface operations
Delivering Efficiency in Performance by Exploiting Advanced Management Information Systems for Well Integrity Processes
Authors: Al Ashhab Jamal , Khreibeh Hana Abu 
Published: November 2008

Abstract
Well integrity data is one of the most critical data types in oil production companies. Since this data is a valuable asset, ensuring its availability and reliability must be taken into consideration to avoid unsafe situations and potential catastrophic consequences. ZADCO has recognized this concern and thus makes continuous use of Information Technology to streamline its business processes.
This paper outlines the best practices for data management implemented by the Well Integrity Team to boost its business performance. These practices ensure achievement of effective and efficient business processes to cope with today's dynamic, fast-paced business environment. The deployment of Information Technology and its capabilities designed appropriately to serve the business, management and organizational needs result in robust Information Systems that achieve business objectives and save resources, effort and time.
Removal of Overburden Channel Effects through Channel Velocity Modeling and Prestack Depth Migration for an Oil Field Offshore Abu-Dhabi
Authors: Takanashi Mamoru , Kaneko Mitsuyoshi , Monzawa Nobuaki , Imahori Seiichi , Ishibashi Toshihisa , Sakai Akio 
Published: November 2008

Abstract
To generate refined depth structure for a very gentle Cretaceous reservoir on an oil field offshore Abu-Dhabi, we conducted channel velocity modelling and prestack depth migration (PSDM). The target reservoir structure on a vintage prestack time migration (PSTM) contains pull-up and push-down artefacts, induced by a couple of overburden channel velocity fills. These artefacts hindered correct representation of gentle depth structure at the target.
Detailed interpretation on the PSTM volume delineates overburden channels in three upper Cretaceous formations. One of them, Fiqa channel, generates small pull-up and the others, Halul and Lafan channels generate push-down below each formation, caused by higher and lower velocity channel fills, respectively. These artefacts overlapped at some locations.
Analysis of synthetic PSTM stack from forward modelling reminded us that a low-velocity channel produces obvious pushdown below the channel. The shape of push-down become smaller but wider with depth and offset. The resulted push-down in full-offset stack also changed with depth. A "true" channel velocity and implementation of PSDM eliminates push-down at all depths and offsets.
Bearing in mind the phenomenon confirmed on the forward modelling, we first produced channel velocity model for the target field data. With the assumption that the depth structure at a layer just below channels is flat, time thickness of channel and the amount of push-down at the layer below the channel could determine the channel velocities. Then, we estimated three channel velocities by channel time thicknesses and the amount of pull-up/push-down at the top Mid-Cretaceous shale, Nahr Umr formation that located just below these channels. On the overlapped area, a linear inversion provided each channel velocity. An application of PSDM with the channel velocity model successfully mitigated the artefact at target depth structure.
Challenges for Integrated Permeability Modeling Incorporating Conceptual Fracture Model in the Jurassic Carbonate Reservoir in a Mature Oil Field, Offshore Abu Dhabi
Authors: Kojima Haruo , Umezawa Yoshihiko , Salman Salman Mohamed , Hosani Khalid E. , Masuzawa Tsutomu 
Published: November 2008

Abstract
"A field" located in offshore Abu Dhabi has produced oil from the Jurassic carbonate reservoirs for 20 years under water injection scheme since 1997 after 10 years gas injection with maximum 20% water cut in some wells. The previous geological model was composed of box shaped fault pattern at down flank area derived from 2D seismic interpretation and mostly considered matrix reservoir properties with unsatisfied history matching quality, especially water cut behavior. In order to improve quality of static/dynamic models, geological model was mainly upgraded focusing on the following subjects: Fault re-interpretation was carried out with reference to analogy from adjacent oil fields, regional tectonic history and dynamic production performance. Radial fault pattern at crestal part in the domal structure was newly introduced.Since well test permeability was obviously greater than static permeability model derived from core plug measurements, fluid flow contribution by fractures was suspected. Hence, fracture density data from cores was reviewed and it is found that more fractures develop at selective layers and near the re-interpreted fault locations. Time-lapse water saturation data confirmed that water movement appeared at low matrix permeability intervals with higher fracture density. A conceptual fracture model was finally established based on the currently available data, and utilized to generate fracture permeability.
These approaches provided multi realization results to assign higher permeability at specific layers and locations related to faults/fractures reconciling well test permeability, although uncertainties remain on the fault interpretation due to lack of 3D seismic data.
It is very difficult to assess each realization and uncertainty including fracture permeability, therefore iterative loops between the geological model and reservoir simulator based on multi-realization models were required to generate a reasonably integrated permeability model. This collaborative process fully incorporating new geological model is in progress and the preliminary updated reservoir simulation using an essence of the conceptual fracture model suggested that matching quality was successfully improved compared with the previous model, particularly water cut behavior.
ADCO's Experience and Lessons Learnt in Managing Major Project Bu Hasa Facilities Development
Authors: Al Jaberi Adel , Hussain Mohamed 
Published: November 2008

Abstract
The objective of this technical paper is to share ADCO's experience during project execution – both in terms of technical and project management issues. It is also highlighting the challenges faced, achievements and lessons learnt during execution of the project and addressing issues related to changing market conditions in terms of availability of quality manpower, vendor assistance during commissioning, falling dollar value, maintaining production during construction and changeover.
The Bu Hasa facilities development project scope is to upgrade the existing Bu-Hasa oil production facilities and centralize the processing units in a new location and to design the system for the new forecasted produced fluid in order to meet the crude oil output specifications. The project includes also building new units / systems for water & gas injection for reservoirs pressure maintenance.
The existing central processing facilities at Bu Hasa consist of four (4) Central Degassing stations (CDS's), which are old and scattered at different locations. These stations independently receive process and export crude through main oil line (MOL) pumping station. Existing auxiliaries such as fresh water supply, produced water disposal, instrument air compressor station, power generation facilities, central control room etc. are also scattered at different locations. The new oil / gas and associated facilities (utilities) will replace the old and centralization of these facilities will be achieved under the Facilities Upgrade.
To maintain oil production from wet wells, facilities are required to handle a high water cut and ensure export crude oil is properly desalted; 20 PTB as total chloride content, and almost water free; 0.1% vol. BS&W.