bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Complexity / High Profile Drilling of the First ADCO Exploratory Well in Salt-Dome Island, HP/HT, with Limited Data"2D Seismic Lines
Authors: Hegazy Gehad Mahmoud , Salama Eid , Al Marzouqi Muna , Ganda Sukesh 
Published: November 2015

Abstract
The objective of this paper is to present the achievements and lessons learnt from a field case study of drilling an exploration well through salt dome with limited data. Also this project introduced drilling with a high efficiency and ‘out of the box’ thinking to deliver a project, that was categorized as high risk and high cost, with optimum cost and zero nonproductive time.
This complex and high profile project was executed against limited time, data and resources. HSE initiatives and innovative ideas to solve engineering and logistical problems were implemented. The project team demonstrated the ability of organization to adapt and succeed when presented with a unique challenge.
The paper will highlight the development of the capabilities of Abu Dhabi Company for Onshore Petroleum Operations Ltd. (ADCO) to drill for the first time from an island and within the salt dome that was critical to support high risk and high cost 3D seismic for future development plan for this area.
The study presents a newly discovered area and the success of this well that has opened a new exploration play into hydrocarbon resources with a high potential economic impact.The paper will highlight the achieved milestones, such as well Design and drilling through the most complex salt dome well thus far drilled in the UAE. Industry experience dictates that salt drilling presents unique challenges and hazards.
Understanding and Overcoming Challenges of Carbonate Reservoir Matrix Stimulation – The Case of an Offshore Abu Dhabi Reservoir
Authors: Ali Issa Abdelkerim , Uematsu Hiroshi , Bellah Samir , Al-Farhan Zahra A. , Al Hashemi Mohamed A. 
Published: November 2015

Abstract
A mature offshore Abu Dhabi oil field produces from a heterogeneous carbonate limestone reservoir with an important column of bottom aquifer. The reservoir heterogeneity is characterized by presence of kurst filled with fine materials at top section, conductive faults, fractures, and significant variation of other rock properties. Most of the main faults cross from the top of the oil column all away down to the bottom of the aquifer. Meanwhile, the field development mainly consisted of horizontal producers targeting the upper section of oil column with peripheral deviated water injectors to sustain reservoir pressure. Generally, producers start with high initial oil rates, but the early decline is steep due to rapid water cut increase resulting into lower well head pressure. Production profiles from PLT combined with FMI indicate that production and water influxes are contributing mainly from the fractured sections of the horizontal drain or through conductive faults. In the meantime, important matrix segments of horizontal drains present very low or no contribution to production. As a solution, surface bull heading and targeted zonal stimulations were performed, which yielded mixed results.
This paper focuses on the analysis of the latest targeted matrix segment stimulation results, which include candidate selection background, description of stimulation method and operations, pre and post stimulation production performance analysis, analysis of main factors affecting carbonate matrix stimulation, and a summary of findings with overall implication to carbonate reservoir matrix stimulation.
CwD Technology Improves Economics in Tight Gas Exploration Project in the Sultanate of Oman
Authors: Briner Andreas , Busaidi Yazeed , Adawi Anwar , Hilditch Robert , Sanchez Francisco , Sanderson Martin , Refai Ahmed , Adly Essam , Nadezhdin Sergey 
Published: November 2015

Abstract
In Sultanate of Oman, use of a casing-while-drilling (CwD) service improved project key indicators for a complex unconventional tight gas exploration project. The technology has been used in 12 wells to date, and the improvement progress has been tracked from the first well. Reaching first hydrocarbon-bearing zone in northern Oman required drilling through the unstable thick Shagri shale, principal element of the Fiqa Formation. Formation swelling and collapse were encountered in the first exploratory wells, which caused significant nonproductive time for reaming and additional trips in hole. To complicate the situation, the naturally fractured UmUeR Formation, located above Shargi, could cause either partial or total losses when drilling conventionally. CwD technology was the selected drilling approach for the subsequent wells in an attempt to mitigate these issues. Although drilling through unstable Shagri shale was still possible with conventional drilling, reaming, stuck pipe and unplanned casing depth become routine operations. The proposed drilling approach proved to be an economically sound alternative to conventional techniques used previously in the field to reduce risk and associated cost. In the Sultanate of Oman, the CwD technology reduced the time of drilling and casing surface holes by 40% in comparison to the field average when using the conventional drilling technique. After drilling 12 subsequent wells with CwD technology, the operations team reported saving of up to 4.94 days per well. Efficiency analyses were conducted, and the technique was fine-tuned for specific conditions.
Pilot Plants: Acid Tests for Researchers in Pushing New Technologies Towards Commercialisation
Authors: Mohd Shariff Shahidah , Abai Mahpuzah , Ishak Mohd Adaham , Lan Lim Fong 
Published: November 2015

Abstract
In any R&D projects, the researchers begin with a Proof-Of-Concept where the research proposal is subjected to scrutiny by a team of experts. If it passes muster, it is then nurtured through stages of development, piloting, deployment and ultimately, commercialization. In PETRONAS, the researchers' share of work has never been confined only at the lab. Once the work has been scientifically or technically proven at lab scale, they are pushed to the hard part of looking into the practicalities and economics of applying the technology into the real world.
Piloting of a technology is a challenge for researchers who have to move beyond their comfort zone of "pure" research to look into a host of factors that determine the success of real life applications of their work. There are countless parameters to consider ranging from costs to risks. Researchers are also expected to forego their "dream" for a perfect technology and accept the imperfections with calculated risks in order to move the technology to the next level. They are anticipated to provide mitigation plans for the risks that come together with the technology deployment to meet every aspect of the safety requirements. The minds of the researchers have been instilled with one clear goal in their pursuits of technologies – bringing them beyond the lab to be deployed in the fields, where they can add values to the Businesses.
To date, PETRONAS has successfully deployed more than 5 pilot plants on various R&D areas to several plant operating sites in Malaysia. This has kept the researcher teams busy and on their toes with the challenges and triumphs of seeing new technologies go live and subjected to real operating conditions. In every step of pushing a technology from lab to pilot and up to commercialization, the researchers have gained many important traits from the science, economics, engineering, operation and commercialization of the technology, hence, producing "all-rounded" researchers. The process pushes them to work and understand the requirements of not only their fellow researchers, but also those people of different backgrounds from engineers who turn their R&D concept to pilot unit to commercial personnel who needs convincing in order to sell their technology.
Through researchers' involvements from lab-scale to pilot, and often up to commercialization of the technologies, a significant leval of knowledge and skill has been acquired together with the developments of tools and methods to successfully deliver new technologies.
Detailed Discrete Fracture Network in Support of Drilling Activities in North Kuwait Carbonate Reservoirs
Authors: Richard P. , Pattnaik C. , Al Ajmi N. , Kidambi V. , Narhari R. , LeVarlet X. , Guit F. , Dashti Q. 
Published: November 2015

Abstract
The North Kuwait Carbonate Reservoirs (NKCR) are currently under development by KOC (Kuwait Oil Company). The appraisal and development of the NKCR offer challenges such as lateral variations in reservoir quality, tight to very tight reservoirs and natural fractures with a high degree of spatial variations. The presence of open, connected fractures is one of the key elements to achieve a successful development. Also, the presence of fracture corridors increases the risk associated with drilling. Numerous fracture modelling studies have been supporting both appraisal and development strategies of the fields.
This paper illustrates how small sector scale detailed DFN (Discrete Fracture Network) can support the planning and drilling activities of future appraisal wells.
A series of detailed DFN models has been built around existing wells. These DFN models are based on a thorough structural understanding combined with a detailed fracture characterisation using bore-hole image (BHI) and core data around the wells of interests. In addition to the fracture characterization work, mechanical stratigraphy has been developed using E-facies and geomechanical logs. Fracture connectivity analysis has been carried out to calibrate the DFNs to the static and dynamic well data. DFN models have also been created around appraisal well locations based on the calibration with the existing wells. These DFN models are now being used to communicate with drilling in order to illustrate the potential distribution of fracture corridors in the sub-surface. These DFN models are also helping to improve the placement of the planned wells with respect to their associated risks and objectives.
Development of a Giant Carbonate Oil Field, Part 1: Fifty Years of Pressure Maintenance History
Authors: Pavangat Vimal , Patacchini Leonardo , Goyal Praffula , Mohamed Farzeen , Lavenu Arthur P. , Aubertin Fabrice , Nakashima Toshinori 
Published: November 2015

Abstract
The giant field considered in this paper, located offshore Abu Dhabi, has so far been developed with solely a pressure maintenance-oriented strategy despite having produced for nearly fifty years. Such achievement has been possible because the field, divided into three stacked isolated reservoirs, is relatively homogeneous with little-to-no flow barriers.
The purpose of this paper is two-fold. First, propose a review and critical discussion of the different pressure maintenance methods employed so far, which chronologically include gravity-driven dumpflood water injection, peripheral powered water injection, and down-flank as well as crestal gas injection.
Second, present a segmentation mainly based on pressure trends on which injection-production metrics can be computed to help reservoir management pinpoint areas lacking support. A key to such analysis in the presence of peripheral water injection is to account for efficient water only, i.e., discard losses to the aquifer. For this purpose, a workflow involving streamline based post-processing of reservoir simulations corroborated by material balance analysis is used.
Recent increasing trends in WCT and GOR indicate that a development solely based on pressure maintenance and reservoir energy (i.e., without artificial lift) is not sustainable anymore, and must transition to sweep-oriented. Plans for such migration are discussed in the companion paper of Nakashima et al. (SPE-177801).
Critical Assessment of CO2 Trapping Capacity Under Gravity Segregation with Capillary Heterogeneity
Authors: Park S. S. , Kim T. H. , Cho J. , Lee K. S. 
Published: November 2015

Abstract
CO2 trapping mechanisms in geologic sequestration have been typically categorized as structural, residual, dissolution, and mineral trapping. However, a storage analysis with fine-scale heterogeneity requires an investigation of newly suggested mechanism, capillary trapping. In addition, CO2 injection process, in which gravity force is relatively strong compared to viscous force, leads to severe gravity segregation and poor contact volumes. This study covers an integrated assessment of CO2 trapping associated with gravity number in heterogeneous formations.
Numerical simulations have been undertaken to evaluate the CO2 trapping efficiency. The effects of formation properties on various CO2 trapping mechanisms are studied with different injection scenarios. Leverett J-function is applied to take account of capillary heterogeneity. Inclusion of capillary trapping enables considerable amount of CO2 to be secured by local capillary barriers. To examine the effects of CO2 gravity override, gravity number, a ratio of gravity to viscous forces, has been introduced. The amount of trapped CO2 and leakage are quantified with the gravity number determined by average permeability, ratio of vertical to horizontal permeability, and injection rate.
Since the overall values of capillary entry pressure are higher in the formation with lower permeability, the larger portion of the lower aquifer can act as capillary barriers, which lead to a large accumulation of CO2 by capillary trapping. Low ratio of vertical to horizontal permeability enables the CO2 plume to spread out more laterally, thus enhancing the CO2 trapping capacity. Under low injection rate, the injection pressure does not have significant impact on the fluids flow and gravity force is dominant. It induces the gas to flow upward shortly after injection, which results in an accelerated CO2 leakage. As the injection rate is higher, stronger viscous force allows the gas to migrate mainly in the horizontal direction. It causes the gas to contact a larger area with brine, so that the amount of trapped CO2 increases. The portion of capillary trapping reduces from 51% to 17% as the gravity number increases. By residual trapping, the immobilized CO2 are 13% and 28% for high and low gravity numbers, respectively. In comparison with residual and capillary trapping, the dissolution of CO2 is insensitive to the parameters associated with gravity number.
For the successful evaluation of CO2 trapping capacity in heterogeneous domain, the results have proven the importance of capillary trapping which accounts for the largest portion of CO2 immobile phase. Integrated assessment of CO2 migration with gravity number is particularly useful to improve the accuracy of CO2 leakage estimation. The workflow will provide simple parameter sensitivity to aid engineers in optimizing CO2 storage design.
Improved Reservoir Management Practice Using Reservoir Performance Indicator Based On the Dynamic Model Uncertainty Study
Authors: Arii H. , Baslaib M. A. , Keshtta O. , Ben Sadok A. , Attia M. 
Published: November 2015

Abstract
At first, the risk assessment of dynamic model parameters based on uncertainty analysis was conducted to evaluate the impact of the reservoir uncertainties in a carbonate reservoir, offshore Abu Dhabi. The study showed that the evolution of gas to oil ratio (GOR) was a main reservoir response that affected the future production profile; hence it is the focus of this paper. It is important to track the GOR behavior in the field, to compare the actual reservoir performance with the risk assessment results and to evaluate the proper reservoir management and development options.
Uncertainty analysis was used to evaluate future GOR performance and its probability of occurrence. The range of production plateau duration was also quantified. Therefore, future GOR performance impact on production for all probability ranges can be estimated.
Finally, "GOR performance indicator" was developed by use of GOR upside and downside performance curves generated as a result of uncertainty studies.
More than three years of monitoring GOR evolution by use of the developed GOR performance indicator allows the assessment of GOR behavior trends against the expected performance, which permits the development of adequate reservoir management plans. The GOR trend can be explained as a result of reservoir management actions such as optimizing gas injection rate, adjusting well production rate and closing high GOR (HGOR) oil producers. Accordingly, the GOR trend can indicate the current reservoir performance compared to the range of uncertainty analysis. It also can put light on required reservoir management action plans for operations and assist building assurance of the reservoir development.
Consequently, the developed "GOR performance indicator" is based on the reservoir simulation outputs for uncertainty analysis. In case that the GOR trend is deviating from the range of the GOR performance indicator, the reservoir simulation inputs needs to be modified.
The developed GOR performance indicator is considered useful to foresee required reservoir management action plans and to suggest alternative development plan needs in case of unfavorable actual reservoir performance. It is noted that the GOR performance indicator can be updated based on new information available. Additional data gathering can support to narrow uncertainty ranges.
Gas Injection as an Enhanced Recovery Technique for Gas Condensates. A comparison of three Injection Gases
Authors: Kumar A. , Gohary M. E. , Pedersen K. S , Azeem J. 
Published: November 2015

Abstract
Gas injection is a recognized enhanced recovery technique for oil reservoirs, but has been given less attention for gas condensate fields. If a gas condensate is produced by natural depletion, the condensate-gas ratio of the produced well stream will steadily decrease after the saturation pressure is reached. The liquid condensed will stay back in the reservoir and will not be produced.
A laboratory study was conducted for a Middle East gas condensate reservoir fluid. Three different injection gases were used- N2, CO2 and a lean hydrocarbon gas. A gas revaporization experiment was conducted with each gas on the depleted reservoir fluid. The gas revaporization experiments showed that injection of CO2 made the liquid dropout in the PVT cell decrease substantially. Already condensed liquid was revaporized and led to an increased liquid content in the released gas. In small concentrations N2 made the liquid dropout increase, but with a continued injection of N2 the amount of liquid dropout declined. The hydrocarbon gas made the liquid dropout decrease at all concentrations, but to a lesser extent than CO2. An analysis of the results showed that injection of CO2 and a lean hydrocarbon gas may substantially increase the liquid recovery from the actual field, while it is questionable whether N2 injection will have much impact on the liquid recovery.
Steerable Drilling Liner Matches the Industry's Common Theme Regarding Cost Optimization Approaches and Minimize Geomechanics Related Challenges; Technology Overview, Applications and Limitations
Authors: Sherbeny Wael El , Dabyah Ali Al , Ghai Gagan , Merie Ibrahim 
Published: November 2015

Abstract
Because fracture gradient changes with rock type, some formations are more sensitive to induced fractures than others. Depending upon depth, the fractures created will either be horizontal or vertical. If the depth is 2500 feet or less, horizontal fractures are usually produced. Because horizontal fractures require lifting the entire overburden, they are limited to shallow depths. At depths over 3500 feet, fractures are usually vertical. Because vertical fractures occur without lifting the overburden, they can be created at much lower pressure. The propagation pressure is generally much less than the pressure that would be required to initiate the fracture. Consequently, fracture losses, once initiated, are difficult to control.
Wellbore instability, particularly in shale formations, is a major challenge in drilling operations. Many factors such as rock properties, in-situ stresses, chemical interactions between shale and drilling fluids, and thermal effects must be taken into consideration in well trajectory designs and drilling fluid formulations to mitigate wellbore instability-related problems.
The Steerable Drilling Liner service combines a rotary steerable system with a liner to help overcome the challenges: drilling in zones with lower pressure and unstable shale/coal layers, and with formations of varying flow and pressure regimes. Running the liner while drilling keeps the wellbore stable and eliminates the need to pull the drillstring to run casing. This is how it reduces your risks and NPT, saving the costs associated with contingency plans. Because the liner is isolated from the reamer shoe, you can rotate the liner at much lower RPMs than the pilot and reamer bits. This design lessens the load on the liner, improving its fatigue life.
The Steerable Drilling Liner steerable drilling liner service helps you to mitigate the risk of hole collapse and formation damage by reducing openhole exposure, Reduce NPT by eliminating extra trips and ensuring that the liner is installed at TD from the first run
Enhance wellbore integrity by drilling with the liner, leading to the plastering effect, which reduces fluid loss and cuttings volume, Lower health, safety, and environmental (HSE) risks by reducing pipe handling and rigsite footprint size
Steerable Drilling Liner service developed and qualified using a rigorous processes including extensive onshore testing at the service provider Experimental Test Area (BETA) facility before being successfully deployed offshore. Rely on Steerable Drilling Liner service performance in extreme environments; the cost-effective Steerable Drilling Liner service promotes wellbore stability and performs reliably in the challenging downhole environments. This Paper will reveal the technology overview, updates, case histories and field limitations
Ecological and Environmental Management During the Hail 3D Transition Zone Survey; Safe Working Practices Within a UNESCO World Biosphere Reserve
Authors: MacGlennon G. S. , Nilsson P. B. , Casson G. A. 
Published: November 2015

Abstract
The Hail 3D seismic transition zone survey, carried out by ADNOC in 2013/2014, was located within an area considered to be of significant national and international environmental importance. Falling within a designated marine protected area ratified by Abu Dhabi ministerial decree as well as a UNESCO world biosphere reserve, high standards of environmental and ecological management throughout the acquisition programme were of paramount importance.
Effective environmental and ecological management throughout the project was attained via the design and implementation of numerous working procedures and monitoring programmes. These included the development of a specific sets of mitigation guidelines for use during transition zone surveys for minimising disturbance and injury to marine mammals and turtles and operating within mangrove areas, the use of environmental profiling, auditing and post operational monitoring, in both the terrestrial and marine environment for collecting new data on the biodiversity and ecology of the area.
For the first time we present ecological and environmental data collected over a period of 12 months within the Hail shoal area. In addition to data on species numbers and distributions we present a method for effectively managing complex seismic surveys being carried out simultaneously in both the marine and terrestrial environment.
For marine mammal and turtle species our results demonstrate seasonal variation in total numbers throughout the year but no significant reduction in observed numbers occurring as a result of seismic exploration activities.
We further demonstrate how a complex seismic survey can be managed and supervised to mitigate and minimize environmental footprint or negative impacts on biodiversity as a result of the exploration and resource development considered crucial to the socioeconomic development of Abu Dhabi.