bluuebunny/crossref_metadata_2025_split huggingface dataset:
IP of Pipelines with Associated Subsea Tie-Ins
Authors: Al Hammadi Hassan , Alshehhi Ebrahim , Hadji Djaffar , Dognon Olivier 
Published: November 2012

Abstract
Mechanical cleaning and Intelligent pigging (IP) are essential to reduce corrosion effect and identify the integrity status of pipelines and to know the weak point within the pipeline to avoid pipeline failure which might have serious environmental and business impact. Therefore, pipeline inspection is critical to ADMA OPCO to assure integrity compliance and determine the remaining life of the pipeline to plan for future replacement.
The Intelligent Pigging is a method of pipeline internal inspection used to detect external and internal metal loss, cracks, geometry defects or video of the internal condition.
Mechanical cleaning and can only be run on pipelines equipped with special facilities in order to launch and retrieve IP tools. IP always needs proper cleaning prior running of the IP tool using cleaning pigs (foam and Bi-Di with brushes). Pipelines without permanent pigging facilities can not IP until temporary facilities is installed (pig traps, pumping facilities, hoses, etc). Pipelines which are attached to other pipelines through Tie-in (Spur lines) are considered not piggable as the pigs can not be received and retrieved. The pipeline without pigging facilities requires longer shut down period than the pipelines fitted with permanent facilities.
Cleaning and IP of pipelines with subsea Tie-in (Spur lines) at their end are not possible as the debris will stay in the pipeline attached and pigs will stay in the pipeline which will result in blocking the pipeline.
The innovative approach was to take the pipeline offline and flood it with water and use Bi-Directional pigs (cleaning and specific IP tool) with direct co-ordination with the contractor. This approach solved and eased the inspection of the Spur lines on the oil and water systems, which has assured the integrity of the Spur lines for the operator.
ADMA OPCO Development of Asset Replacement Plans for 20 Years for Zakum, Umm Shaif and Das Island
Authors: Balmer Brian , Khorooh Ali Saleh 
Published: November 2012

Abstract
ADMA OPCO operates facilities in the Zakum, Umm Shaif and Das island sites more up to 45 years old. The Asset Field Life is expected to extend to more than the next 20 years with existing and New Field production projects currently indentified and future developed also expected.
In this context the Asset Integrity of aged equipment is a major challenge in the oil and gas industry. ADMA OPCO has developed a risk directed strategy to identify, assess and mitigate risk across all existing facilities and develop inspection, assessment practices and maintenance and repair approaches that will provide the asset integrity assurance required for current and future business requirements. The Asset Replacement Plan - 20 Years is under development for all sites based on this risk directed approach. The work described in this paper was carried out in the period 2011 to 2012.
Key aspects of the asset replacement plan include the principle that ADMA OPCO will seek to fully utilize the existing equipment capabilities, consider improved practices for inspection, maintenance and remedial works, recognize the potential impacts of Brownfield Project developments and link all existing Development, Engineering, Maintenance and Integrity studies and identify where additional studies are required.
The deliverables from this across the ten identified equipment types include;
An equipment strategy to meet business requirement. Plan for equipment and improved practices opportunities Costs by year of replacement expenditures Supporting links to existing studies supporting the strategy and plans
The paper provides the background and business benefits of the development of the Asset replacement plans, the approach taken to develop strategy, plans and costs. The discussion is supported where appropriate by description of the development process, example case to explain issues faced, decision a making and the basis for the final results.
A Unique Integrated Asset Modeling Solution to Optimize and Manage Uncertainty in a Giant Offshore Oil Field Development Mega-Project
Authors: Khedr Osama , Amur Jayant , Al Ameri Rakkad , Torrens Richard , Amtereg Ahmed 
Published: November 2012

Abstract
This paper presents the application of an integrated modeling approach to the facility design and construction stages of a mega-project for a giant oilfield offshore Abu Dhabi. The scale of the EPC task is unprecedented in the UAE and requires careful design to optimize the capital investment. In addition, the project uncertainties require that a high degree of flexibility be factored into the design process.
The integrated modeling approach couples surface and subsurface flow models to achieve a complete system solution that incorporates many levels of constraints and realistically represents future behavior. This approach addresses a number of key issues. Firstly, multiple different quality reservoirs produce to a shared surface facility. Consequently, the field is highly sensitive to back pressure variation and so requires a rigorous treatment of well and surface physics. Secondly, the sub-surface uncertainties and sheer size of the investment requires a flexible approach to design, hence, many simulation scenarios are required to provide improved decision support. Finally, close collaboration is required between the sub-surface and surface teams to ensure optimization of facilities design and reservoir management for cost and recovery. The adopted methodology utilizes an integration framework which couples reservoir and topsides models into a predictive tool for development planning. This paper describes how the integrated modeling approach was utilized to provide input to design process for several aspects of the field development plan during the design and construction stages. This will include discussion of the phasing of the production facilities, requirement for temporary facilities, modular compression and separation units and the optimization of the drilling program for planned infill wells.
The paper presents a best integrated modeling practice supporting facility design process which is applicable for similar scale projects, highlighting the role of integrated model as a means to foster collaboration between surface and sub-surface teams.
Successful Application of Extended Reach Drilling (ERD) Technology in Super Giant Onshore Middle East Field, Case Study
Authors: Al Shamsi Juma , Al Menhali Adnan Mohammed , Hamdy Ibrahim , Parkinson Andrew , Kuyken Chris 
Published: November 2012

Abstract
Extended reach drilling (ERD) represents one of the industry's most impressive engineering accomplishments in terms of wellbore construction. As the recovery of oil and gas becomes more complex, these wells have pushed drilling engineering boundaries to new limits to meet the world's demands in the safest, most environmentally conscious and cost effective manner. Drilling ERD wells requires the latest innovations in drilling engineering principles; such wells are more interrelated and sensitive to smaller changes than conventional wells. An integrated approach for both planning and execution becomes more critical due to the high operational risks and all uncertainties must be properly assessed by solid engineering planning. In addition to that, it brings engineering challenges from many disciplines, which must be met and addressed for proper execution. Integration of drilling and real time evaluation allows engineers and geoscientists to take the proper drilling decisions and lead to reduce operational risk. It will also provide an accurate well placement; improve drilling efficiency and maximum recovery.
Well-1 & Well-2 were the latest ERD wells drilled in Abu Dhabi. Abu Dhabi Company for Onshore Oil Operations (ADCO) has drawn on extensive experience from numerous ERD Projects around the world, successful engineering tools and proper assessment for the several of challenges of those projects. In addition to the positive contribution from National Drilling Company (NDC) in providing all the necessities in terms of equipment and support which enabled the land rig to drill the well Well-1 to a total depth of 19,725 ft MD with a horizontal displacement (HD) of 10,131 ft. In addition, Well-2 was drilled to a total depth of 20,003 ft MD with a horizontal displacement of 10,303 ft, which was a bench mark record in the United Arab Emirates (UAE). The numerous challenges faced on those two wells in terms of planning and the rich experience gained from successfully executing such wells are all highlighted in the attached paper.
Best Safety Practices for New Drilling Rigs, ADCO's Successful Precautions Approach
Authors: Karrani Sultan Mohamed , Boucif Mustapha Nasreddine , Carvalho Rui , Kuyken Chris , Kerr Brad 
Published: November 2012

Abstract
Abu Dhabi Company for Onshore Oil Operations (ADCO) has recorded the lowest Total Recordable Case Frequency (TRCF) of 0.52 in its history. This is also a drilling worldwide record and it was achieved, despite ADCO have increased its drilling fleet by around 30%. This successful score could not have been achieved without proper planning and implementation of the new rigs, especially with limited resources and through very tight schedule to meet ADCO's business plan requirements.
An assessment to our project leads us to collect all the inputs related to the best way for the safe start up of the rigs. Taking in consideration the changes in design and shortage in crew staff, we have built a detailed plan for the safe start up rigs with all the parameters such as human recourses, management involvement, and technical inspections. Furthermore, we have developed plan to be in three stages: commissioning, rig move, and rig spud for the first well. Being HSE the focus with the start up of the new rigs, the main challenge faced by the project team was to ensure the implementation of every step in our HSE plan. This allowed us to safely start up the new rigs while delivering the required operational performance despite the fact of staffing the rigs with about 50% green hats crews. For both operator and contractor, the responsibility for safety, health of workers and environment has increased due to considerable impact of strategic growth plans and additional workload. For the major projects like rig expansion we have applied the best functional planning for safety management system.
This paper will discuss and review the methodology for the rig start up plan and implementation of the primary actions needed to be developed and monitored through minimizing the risk and the impact to the project cost and schedule. Success, failures, and lessons learned are highlighted through the sections in order that full knowledge of the current project is captured and mitigated in the ongoing expansion with additional rigs being ordered. This will enable ADCO to enhance HSE commitments ensuring new rigs are delivered ahead of time.
Flotation, Filtration, and Adsorption Pilot Trials for Oilfield Produced Water Treatment
Authors: Al-Maamari Rashid S. , Sueyoshi Mark , Tasaki Masaharu , Okamura Kazuo , Al-Lawati Yasmeen , Nabulsi Randa , Al-Battashi Mundhir 
Published: November 2012

Abstract
As an oil field matures, it produces larger quantities of produced water. Appropriate treatment levels and technologies depend on a number of factors such as disposal methods or reutilization aims, environmental impacts, and economics
In this study, a pilot plant of capacity 50 m3·day−1 was utilized to conduct flotation, filtration, and adsorption trials for produced water treatment at a crude oil gathering facility. The plant's flexible design allows for the testing of different combinations of these processes based on the requirements of the water to be treated. The subject water during this study was a complex and changing mixture of brine and oil from different oilfields.
Induced gas flotation trials were conducted, with different coagulant (poly-aluminum chloride or PAC) addition rates from 0-820 mg·L−1. Inlet oil-in-water (OIW) concentrations were quite varied during the trials, ranging from 39-279 mg·L−1(fluorescence analysis method) and 12-340 mg·L−1 (infrared analysis method). Turbidity also varied, ranging from 85-279 FTU. Through flocculation/coagulation and flotation, dispersed oils were removed from the water. PAC addition ranging from 60-185 mg·L−1 resulted in reduction of dispersed oil concentration to below 50 mg·L−1 in treated water. PAC addition ranging from 101-200 mg·L−1 resulted in reduction of dispersed oil concentration below 15 mg·L−1 in treated water. Turbidity was also reduced through flotation, trial average reductions ranging from 57-78%. Filtration further reduced turbidity at rates above 80% through the removal of any suspended solids remaining from flotation. Activated carbon adsorption reduced OIW concentrations of flotation/filtration treated water to 5 mg·L−1 through the removal of dissolved oil remaining in the water. Results confirmed that such adsorption treatment would be more practical for water with lower COD concentration, due to high COD concentrations in water drastically reducing the lifetime of activated carbon.
Optimization of Effective Horizontal Length Utilizing Underbalanced Technique
Authors: Al Menhali Adnan Mohammed , Belhaj Hadi 
Published: November 2012

Abstract
Over the last two decades, horizontal wells are still more favorable over vertical ones because they maximize reservoir contact and increase productivity index. In addition, horizontal wells yield higher drainage area and reduce water coning impact. Many horizontal drilling patterns have been evaluated in terms of distance between wells and the length of horizontal section heel to tail.
EHL (Effective Horizontal Length) has a great impact on EDA (Effective Drainage Area) of a horizontal well which can be used as indicator to evaluate the success of field development. Many data can be collected and extracted by remote real -time monitoring. These data can be used to estimate very important factors like reservoir permeability and drainage area at each foot of the horizontal section.
This paper presents a new approach of investigating EHL by using UBD (underbalanced drilling) data. Simulation studies were conducted through the horizontal section trajectory of the well to determine the reservoir drainage area along the length of the horizontal section. Eventually, the evaluated EDA summed up to produce the total productivity of the well using nodal analysis for each section separately. Results of this study showed very promising potential for actual field applications.
Improved Understanding of Static and Dynamic Geomechanical Stability and BHI Data Integration: Key for Improving the Completion of a Horizontal Well in Tiered Complex of Laminated Unconventional and Fractured Carbonate Reservoirs
Authors: Acharya Mihira N. , Kabir Mir R. , Al-Ajmi Saad A. , Pradhan San P. , Dashti Qasem M. , Al-Anzi Ealian H. , Chakravorty Sandeep 
Published: November 2012

Abstract
The deep, sub-salt reservoir complex is tiered with fractured tight carbonate at bottom and top, with the two sub-units of "upper unconventional kerogen" and "lower inter-bedded kerogen-carbonate" in the middle. This depositional setting is challenging for horizontal well placement where the thicknesses of respective sub-units are about 50 and 30 feet with varying geomechanical and petrophysical properties. Additionally, this complexity poses limitations in completions and effective stimulation of the Kimmeridgian-Oxfordian reservoirs in several gas fields at development stage in Kuwait.
A horizontal well is placed in the lower sub-unit of the laminated complex of unconventional kerogen and fractured carbonate reservoir as a Maximum Reservoir Contact (MRC) type well. A pilot mother-bore was drilled and logged to identify the lithological properties across the entire vertical domain - facilitates the optimization of horizontal drain-hole placement within the targeted reservoir units.
No wellbore stability issues in drilling were predicted based on the geomechanical understanding where core-calibrated logs from offset vertical wells were considered. However, this modeling method did not have the functionality to integrate the impact of drawdown on the laminated formation which became unstable and collapsed during the short open-hole drill-stem test (DST) plugging the tubing prior to the final completions. An alternative "book-shelf" geomechanical model was considered at pre-drill stage for predicting the wellbore stability. Once the drilling was completed, the time-lapsed multi-arm caliper indicated the validity of the alternative methodology in predicting the unstable stack of laminations in kerogen-rich strata.
The paper discusses an optimization methodology to enhance the understanding of static and dynamic geomechanical stability through the use of BHI data. Objective of the proposed method is to help improve the effectiveness of completions where wellbore stability due to geomechanical complexity in stacked-pay reservoirs is a primary wellbore challenge in deploying the completions and executing a subsequent stimulation and testing campaign.
Paper Title Asset Monitoring by Wireless Technology
Authors: Mukherjee Somen 
Published: November 2012

Abstract
No matter where an asset sits in the plant, the need to understand its health on a real time basis has become increasingly vital mainly because of growing need to focus on HSE commitments, intense global marketplace and high energy costs, safer and greener work environment. While most facilities continuously monitor their critical machinery and asset, their less-critical assets - often called "essential assets" - cannot typically justify the expense of a traditional continuous monitoring system due to the installation costs of running wires and sensors. Today there is a growing proliferation of wireless devices for many industrial and commercial applications - for security, safety, surveillance and machinery condition monitoring. Wireless technology innovations promise to open up a wide range of plant floor applications where cabling is either difficult to install or prohibitively expensive.
Some Thoughts of Acquisition Footprints Removal on 3D Seismic Data
Authors: Mahgoub Mohamed , Al Mesaabi Saif , Hagiwara Hiroshi , Matarid Tarek , Nakayama Shotaro 
Published: November 2012

Abstract
Acquisition footprint is a pattern on seismic data which is mainly caused by the sparseness of the acquisition geometry. It hinders seismic interpreters from accurate structure analysis by masking geological significances such as fault lineaments, channels and karsts. It is triggered by coherent changes in case of variable acquisition parameters and/or methods in the field, or alignments caused by the direction of data acquisition, and it is predominant on sparse acquisition geometries. Furthermore, it might be accentuated by multi-channels seismic processing such as stacking, DMO and pre-stack time migration if the aliased noise produced by the sparse geometry does creep into the seismic data.
In general, the acquisition footprint signature is rather strong in the shallow events due to relatively lower fold. Hence, it is strongly dependent on trace mute designs and sensitive to the amount of moveout and NMO stretch, where the influence is progressively healed with depth due to higher fold, wider mute parameters and smaller NMO shift.
It is known that remnant acquisition footprints often exist on the data after the application of the 3D F-Kx-Ky wave number notch filter. Although it may not always appear on the vertical cross-sections and time slices prominently after the attenuation, it might be pronounced on edge detection attributes, such as coherency cube, curvature and/or seismic impedance. There is some ongoing debate in Abu Dhabi between processing geophysicists and interpretation geophysicists as to whether apply harsh filter to clean up the residual footprint or to be more conservative while preserving some desirable subtle geological features as possible.
This paper advocates the necessity of time-variant 3D notch filtering approach regardless of the acquisition geometry and/or the area by showing some case histories from 3D seismic surveys offshore and onshore Abu Dhabi with three different acquisition geometries; orthogonal OBC patch layout, orthogonal land layout, and parallel OBC patch layout. Change of footprint characteristics in time, in association with adaptiveness of various notch filters in temporal/spatial domain, will b e discussed and demonstrated for each geometry type.
Well Log Conditioning for Quantitative Seismic Interpretation
Authors: Al Shekaili Fatema , Chacko Soman , El Din Samy Serag , Yin Yahui , Aurelie Pujol , Gael Lecante 
Published: November 2012

Abstract
Reliable sonic and density logs are needed for calibration of seismic data for use in reservoir characterization, and for specialized AVO and 4-D analysis. Due to the small depths of investigation of sonic and density logging tools, measured logs are affected by borehole washout and mud filtrate invasion. In many wells, particularly older ones, density and shear sonic logs were acquired within limited depth sections, or not at all. To address these various log quality issues and make the logs suitable for use with seismic data, appropriate log editing must be done, and missing logs or log sections must be synthesized. In addition, complex waveforms measured by modern sonic logging tools must be processed before they can be used for geophysical analysis, a step often ignored by geophysicists.
Our paper presents a sequential workflow to address sonic and density well log quality issues for approximately one hundred wells penetrating multiple carbonate reservoirs within a supergiant field from the Middle East. Borehole washout problems are frequent in the shales that overlie the main reservoir of the field, resulting in poor sonic and density log measurements. Within the reservoirs, high salinity filtrate invasion that displaces light oil affects both sonic and density log measurements. To address these issues, we developed a well log conditioning workflow that involves the following steps:
- Processing of sonic logs from wells with dipole sonic measurement - QC of all well data, and selection of wells with optimal logs for building a training data base - Generation of missing data using multi-variate statistical analysis - Correction of borehole-related anomalies - Correction for invasion effects - Validation against VSP and seismic data.
Results of log conditioning have improved well-seismic ties. In many cases these ties confirm the presence of residual interbed multiples within the 3D seismic data that covers the field. Modeling of fluid effects during invasion correction shows acoustic impedance to be sensitive to both porosity and fluid effects: up to 9% change occurs in acoustic impedance due to invasion-related saturation changes. Such saturation-related effects suggest the feasibility of 4D seismic as a surveillance tool in future FDP of the carbonate reservoirs in this field.