bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improving Oil Recovery in Heterogeneous Carbonate Reservoir By Optimizing Peripheral Water Injection through Application of Innovative Techniques
Authors: Chaudhry M. A. , Mahmeed A. A. , Wani M. R. , Mubarak H. A. , Thakur R. K. , Al-Rashidi H. R. 
Published: March 2009

Abstract
Excellent benefits in terms of oil recovery and economic returns can be achieved in heterogeneous carbonate reservoirs by optimizing water flood through continuous application of innovative techniques in reservoir management. The fact is illustrated in this paper by sharing the challenges and success of Kuwait Gulf Oil Company (KGOC) and Saudi Arabian Chevron (SAC), in the Wafra Oil field, located in the divided zone between Kuwait and Saudi Arabia. Peripheral water injection was initiated for Wafra-Ratawi reservoir in 1998 after extensive studies. The project provided excellent results in the first 5 years in terms of increased production rate, reduced GOR, managed water cut and improving ultimate recovery. The project faced major challenges, such as early water breakthrough in the first row of producers, development of low pressure pockets and increased GOR during the 6th year of its life.
The paper presents an overview of the innovative technology and principles of reservoir management utilized at each stage of project to maximize asset value to all stake holders of the joint venture. Five topics are covered. First, the challenges faced and the solutions implemented during the early phase of water injection. Second, it covers the application of available technology at proper time. Third, it documents the modifications employed in the water flood strategy utilizing bottom water injection through horizontal wells and sidetracking the existing producers and optimizing injection profile with integrated reservoir models, dump flooding in low pressure areas. Fourth, synergy approach to reservoir management has been discussed, and finally, the future potential and way forward is outlined. Application of the innovative technology at proper time has resulted in significant increase in production rate, ultimate oil recovery and asset value.
Sharing the Best Practices and lessons learnt while implementing the reservoir management strategy can benefit the industry in recovering more oil.
Medium Radius Horizontal Sidetrack Reduces Time, Cost and Risks in Deep HT Gas Wells
Authors: Simpson Michael A. , Al-Hamid Abdul , Faraj Yusri , Khalil Mohamed , Duran Roberto , Miller Clayton L. , Al-Khamees Shaker , Stewart Jeffry 
Published: March 2009

Abstract
Saudi Aramco's first medium radius horizontal sidetrack gas well, Haradh-AX1, was drilled and completed in June, 2008 in a record time of 48.7 days with 4,989 ft of reservoir contact and a 33% reduction in overall cost.
The previous, Khuff-C Horizontal sidetracks which included the same operations; de-completion, sidetracking and re-completion, averaged 83 days with 3,441 ft of sidetracked lateral across the Khuff-C.
Directional drilling in the medium radius lateral after building at 12°/100 ft to a sail inclination of 88° was characterized by better bit performance, lower torque and drag, improved wellbore stability and steerability.
In the previously employed long radius horizontal sidetrack design, extensive milling operations were required to gain access to the 8-3/8 in. open hole to sidetrack. The 8-3/8 in. long radius build section would then be drilled from the Base Jilh Dolomite, across the troublesome and sometimes abnormally pressured Lower Jilh and Sudair Shale formations to the top of the Khuff-C where a new 7 in. liner would be run and cemented. The 5-7/8 in. lateral would then be drilled across the Khuff-C and an open-hole completion run.
In the medium radius design, the sidetrack (ST) could be made deeper, in the same pressure regime, by cutting a ST window in the existing 7 in. liner 450 ft true vertical depth (tvd) above the Khuff-C target reservoir, kicking off and drilling 5-7/8 in. hole across the Khuff-C to total depth (TD).
This paper further details the time and cost savings possible from the application of proven medium radius drilling technology from Saudi Aramco's Arab-D Horizontal Oil wells produced from 6,500 ft tvd to the deep gas wells produced from the Khuff formation at 12,000 ft tvd, a new drilling environment.
More medium radius horizontal sidetracks are planned and a similar medium radius Khuff-B Horizontal ST, ANDR-AX1, which built at 32°/100 ft, was just successfully completed at 14,819 ft with a 2,400 ft horizontal section.
Successful Mitigation of Deepwater Shallow Flows in the East Mediterranean Region—Case Histories
Authors: Lopez Jesse , Garrett Don , Zanaty Akram , Waheed Arshad 
Published: March 2009

Abstract
In 2008 deepwater drilling marked a decade of operation in the Nile Delta region of the East Mediterranean Sea. The operating water depths ranged from 200 m to ultra deepwaters greater than 2600 m. The Nile Delta region has been no exception to the challenges of shallow gas and water-flow hazards observed in many of the deepwater projects of the world (Furlow 1998; Alberty 1998). An obvious consequence of an unexpected, shallow-fluid flow is an uncontrolled blowout situation with no drilling control equipment in place. In some reported cases, even after the flow was controlled before running casing, fluid flow occurred after cementing the surface pipe. Incidentally, this phenomenon is not only limited to deepwater operations in Egypt; similar blowout situations can be observed anywhere in the offshore Nile Delta.
This paper reviews two recent examples of shallow flows that occurred in the surface holes of two different wells. Each operation cost the operator between 1.5 and 4 million dollars to address the problem. Alternatively, several examples are also provided that illustrate how understanding the flow mechanism, predicting its occurrence, taking necessary precautions while drilling, and designing cement slurries suitable for deepwater cementing have resolved the issue. Proper well preparation, correct mud design, and foamed cementing have been effective solutions. Additionally, advances made in cementing designs for deepwater situations with low margins between pore pressure and fracture gradient, cool seabed temperatures, and unpredictable shallow flows, each working adversely on the slurry design, are discussed to help deliver safe and competent wellbores.
Analysis of Deposition Mechanism of Mineral Scales Precipitating in the Sandface and Production Strings of Gas-Condensate Wells
Authors: Franco C. A. , Solares J. R. , Al-Marri H. M. , Mukhles A. E. , Ramadhan N. H. , Saihati A. H. 
Published: March 2009

Abstract
Thick deposits of various types of mineral scales are presently forming in the tubulars and formation of gas producers drilled in Saudi Arabian carbonate reservoirs. These mineral scales precipitate when ideal thermodynamic conditions and dissolved minerals present in formation waters combine. Without remedial action over time, these deposits can grow thicker and end up plugging tubulars and the reservoir.
Thick deposits of mineral scales have recently begun to appear in gas producers in certain areas of the field. A comprehensive study was conducted to ascertain the nature of the precipitation mechanism and identify potential solutions to the problem. This paper details how laboratory analysis data, well production history, reservoir geology and petrophysics, and reservoir description were analyzed and used with sophisticated computer software to identify the formation damage mechanism and the different scale types precipitating in the wellbore and formation. Extensive simulation work was conducted as part of the study to forecast the type and amount of mineral scale precipitation that can be anticipated at varying reservoir and producing conditions. The study also evaluated the most cost effective and feasible ways to remove different types of scale deposits.
The future scale inhibition and removal strategies to be implemented in existing and future gas producers are being derived in large part from the results of the study described in this paper.
Characterization of Complex Carbonate Heavy Oil Reservoir—A Case Study
Authors: Iqbal Afzal , Smith John , Zahedi Ali Reza , Arthur Deemer , Al-Yami Falah M. , Meddaugh W. Scott , Rampurawala Mansoor A. , Li Bingjian , Gok Ihsan , Al Enazi Talal 
Published: March 2009

Abstract
The Paleocene/Eocene age 1st Eocene Reservoir is the shallowest producing interval of Wafra Field in the Partitioned Neutral Zone (PNZ), Saudi Arabia and Kuwait. Characterization of this heavy oil reservoir is challenging due to observed variations in oil viscosity, heterogeneity related to complex mineralogy, a possible dual porosity system, and the presence of fractures at varying scales. This case study of the 1st Eocene reservoir characterization in the steam flood pilot area will improve our understanding of the range and distribution of formation properties which is critical for management of the current pilot project.
This study presents several aspects of an integrated approach to characterize the 1st Eocene reservoir. The approach includes the quantification and distribution of the evaporite minerals and porosity, analysis of a possible dual porosity system, and evaluation of permeability using a new porosity partitioning technique. Data used in this study includes conventional open-hole well logs, borehole images, nuclear magnetic resonance (NMR) logs, Elemental Capture Spectroscopy (ECS) logs, formation pressure measurements, and routine core analysis. The porosity partitioning model allows the core porosity-permeability relationship to be reproduced from logs by incorporating dual porosity information. The integration of NMR logs and image logs used in the porosity partitioning model provides a well log based permeability that has a good correlation with core plug data.
Fracture and Sub-Seismic Fault Characterization for Tight Carbonates in Challenging Oil-Based Mud Environment—Case Study From North Kuwait Jurassic Reservoirs
Authors: Li Bingjian , Al-Awadi Mishari , Perrin Christian , AL-Khabbaz Mohammed , AL-Ashwak Samar , AL-Qadeeri Bashar 
Published: March 2009

Abstract
Evaluating natural fractures in tight carbonate reservoirs during the exploration and early development stages is critical in order to reduce geological uncertainty and determine well trajectory in future horizontal drilling. Challenges are often found in both acquiring the adequate data and assessment of the fractures/sub-seismic faults in the oil based mud borehole environment.
This paper summarizes part of the experience learned from the use of an optimal dataset in addition to a workflow on fracture characterization for tight deep carbonate reservoirs in Kuwait. In the process of exploration and development of these particular reservoirs, oil-based mud has been used in the drilling process due to the concerns of wellbore stability. Acoustic images and core was acquired in the early stages of the field development. After the invention of a micro-resistivity imaging tool it was used in combination with the acoustic imaging for integrated and enhanced formation evaluation, which allowed reduced coring for a cost saving. The paper explains the advantages and limitations of each image dataset and describes how the acoustic and micro-resistivity images are complementary to each other. The paper also presents how different datasets gives partial contribution to the overall geological understanding of the field. More importantly, the case study shows that the combination of both image data sets provides a much better and more complete picture of fractures in the wellbore with limited core calibration. Smaller scale faults, which are usually not detected or poorly imaged on seismic, can be interpreted on images with definition of vertical displacement through the integration of well correlation and cross sections. The output from this study provides an essential database for well completion decision, fracture reservoir modeling, infill drilling plan and future horizontal well placement.
Lessons Learned From the First Water Flood Pilot Project in a Clastic Reservoir in the Greater Burgan Field in Kuwait
Authors: Al-Naqi Meqdad , Al-Kandari Ibrahim , Al-Qattan Mishari , A/Rahman Badria , Bou-Mikael Sami , Gazi Naz H. 
Published: March 2009

Abstract
Greater Burgan in Kuwait is the second largest field and the largest clastic reservoir in the world. Discovered in 1938, the production initially came from Wara sandstone and soon followed by other underlying Burgan clastic reservoirs. Burgan reservoir mainly consists of three reservoir units namely Wara, Third, and Fourth sand. The Wara Water Flood Pilot Project is the first clastic waterflood pilot in Kuwait.
Reservoir pressure in Wara has been falling below the bubble-point in many parts of the reservoir. This would ultimately result in free gas evolving from the oil and significant loss in reserve recovery. This pilot was designed with the objective to obtain information in the areas of: Long-Term InjectivityReservoir ConnectivityWater Breakthrough Time and DirectionWater-Cut DevelopmentProductivityOperational Experience
The Wara pilot pattern is of inverted seven spot with one injector, six producers, and one water source and was designed to inject 5,000 to 10,000 bwpd into a single injector and to produce from six producers drilled around the injector. Each well is 250 meters apart and the producers are equipped with ESPs to produce even after water breakthrough.
The project has been in the operational phase for the last two years and the main objectives of evaluating long-term injectivity and the reservoir response to water injection in the Wara reservoir were achieved.
Results from this pilot were needed to reduce subsurface uncertainty and to support the design of future Wara waterflood projects. This will ultimately help in the decision of whether to build a permanent water flood project to maintain a stable reservoir pressure in the Wara reservoir.
This paper highlights the challenges and accomplishments in designing, completing, and operating of this successful water flood pilot project which could benefit other similar projects around the world.
From Data Acquisition to Simulator: Fracture Modeling a Carbonate Heavy-Oil Reservoir (Lower Shuaiba, Sultanate of Oman)
Authors: Warrlich Georg M. D. , Richard Pascal D. , Johnson Timothy E. , Wassing L. Bart M. , Gittins James D. , Al-Lamki Ali , Alexander David M. , Al-Riyami Murshid 
Published: March 2009

Abstract
A dedicated appraisal campaign and modeling study was carried on a heavy-oil, fractured Shuaiba field in the north of the Sultanate of Oman to assess the feasibility of steam-assisted gas-oil gravity drainage (SAGOGD) EOR. In this field, key to a successful SAGOGD is a well-connected fracture network, which was investigated by a dedicated appraisal campaign which included drilling one vertical and 3 near-horizontal wells. BHI, sonic and resistivity logs were run to understand static fracture characteristics; dynamic behavior was assessed with DSTs and PLTs. Fracture models were built with forward modeling algorithms using Shell's fracture modeling software (SVS Fracture-Solution). They are based on fracture characterization that integrates the well data with 3D seismic, field kinematic structural evolution and the regional understanding established by Petroleum Development Oman's (PDO) long-term activities in the area. This integration makes the fracture models more realistic than purely stochastic fracture models that only honor the statistical field data.
Interdisciplinary collaboration during data acquisition and all stages of the modeling assured that only the features relevant to the dynamic behavior of the reservoir were modeled while at the same time the geological details of matrix and fracture models were captured sufficiently in the simulator. Simulations were run in dual porosity dual permeability thermal mode in Shell's dynamic simulator (MoReS). The results are fully integrated model scenarios that can be compared quantitatively with all other PDO fractured Shuaiba fields, facilitating management's technical decision making on the EOR strategies for the fields.
Full-Field Development Plan "The Big Picture—Creating the Future from the Future and Success through Real Synergy"
Authors: Hafez Hafez H. , Kenawy Maher M. , Keshka Ashraf Al-Saiid , Samad Khalid Abdul , Al-Bakr Salem , Al-Dhiyebi Shaffique 
Published: March 2009

Abstract
This paper represents a case history of a full-field development plan for one of the major fields (field "A") in Abu Dhabi Company for Onshore Oil Operations (ADCO-UAE) consisting of three different reservoirs. Field (A) development is becoming increasingly complex and expensive as this field acts as a hub for another two producing fields and several undeveloped fields. This involves developing an efficient design and planning philosophy. Best practices in integrating new technologies in materials, construction, operations as well as management techniques including the right team to really be successful are all part of the "big picture".
ADCO assigned a cohesive and highly motivated team involved in the ‘big picture" event with a clear direction in terms of policy, risks and implementation aimed to shorten the decision process without compromising the company Major Project Approval Process (MPAP) requirements and Shareholders guidelines.
The Project Management main factors that were tackled successfully during this event were the focus on profitability and increase of NPV by adopting a multi-disciplinary approach to field management; align various departments involved right from the concept to the implementation stage through continuous interaction; cultivate an open-ended approach to all aspects of engineering and Field Management by taking into account both the surface and subsurface perspectives of oilfield Project Management.
The paper will also address the structure of the team and how it set feasible targets in terms of production building blocks of other fields through eventual expectations in terms of surface facilities and helped in overcoming challenges and minimizing risks through careful integrated risk register. Finally assessed specific problems and issues relevant to the field operability and evaluate possible strategies to tackle it.
The key objective and achievements of the event were the deliverables for the Stage-4 of the MPAP. The paper will discuss the achievements as a result of this event. The integration of the development options alternatives, into a single development plan enabled shortening the decision process and secured Shareholders approval on Gate-5 finance proposal as it was recognized as an economically favorable development opportunity. The development plan continued to other Gates (7 & 9) with the same approach in order to properly accomplish the success of such plan with a value of multi Billion USD.
Specialized Techniques for Formation Testing and Fluid Sampling in Unconsolidated Formations in Deepwater Reservoirs
Authors: Jackson Richard R , De Santo Ilaria , Weinheber Peter , Guadagnini Emilio 
Published: March 2009

Abstract
Wireline formation testing (WFT) and fluid sampling has long been used for determination of reservoir pressure, evaluation of fluid type from in-situ densities, identification of fluid contacts, and inter-reservoir connectivity. Fluid sampling and downhole formation fluid analysis measurements also provide information for assessment of fluid complexity, compositional grading, and acquisition of samples for input to PVT studies.
Many deepwater reservoirs comprise of young turbiditic formations, which even at great depths remain unconsolidated or only weakly cemented. Experience has shown, when sampling fluids from such formations, sand grains and solids tend to become mobilized and flow with the fluid being sampled. In some circumstances where significant formation solids and sand are mobilized, deposition of suspended solids can result in the premature ending of formation testing and sampling jobs, or require multiple trips into the well to acquire the required samples and fluid profiling stations.
To limit excessive sanding and solids production, and mitigate problems of plugging during sampling operations, the conventional approach has been to reduce the pressure drawdown, and limit pump speed and flow rates. To increase tolerance to solids production during sampling operations, various filter and pump options are available for the different probe, focused probe and dual packer tools - as well as enhancements to improve pump performance in the presence of high solids content. Such approaches are not always successful.
In this contribution we describe an innovative solution to unconsolidated sanding problems during sampling and advanced fluid profiling, and its practical application for deepwater exploration and appraisal operations using several field examples. Suspended solids pass through an inline filter sensor module, where the particles are trapped and deposited, allowing fluid with little or no particles to pass through the formation tester tool. This results in greater reliability and efficiency for formation testing and sampling in unconsolidated formations.
Climate Change: Facts, Science & the Dispute Regarding the Environment
Authors: Hamilton J. , Vossoughi S. 
Published: March 2009

Abstract
The measured increase in the Earth's temperature combined with a rise in average ocean temperatures, have prompted predictions of catastrophic results from severe global warming. The climate change and the variety of causes with which it is associated are being reviewed here.
The paper reveals that the experts in this field are distinctly and passionately in disaccord. The only point the opposing scientists agree on is that there is some level of global warming. There is little, if any, agreement on any other aspects of the subject matter.
Current measurements show a marked increase of average air temperature near the Earth's surface, especially within the last decade. Moreover, these increases in temperature have caused scientists to further examine and predict future temperature changes. These changes present a dire outlook that lead to drastic results for the environment and future human activity through the 21st century. Despite research and data that support the accuracy of the causes, there are prominent scientists that dispute the theory that human activity and the industrial economy are the root causes of climate change. Undoubtedly, the natural cycles of both the sun and Earth are the underlying causes of expected and cyclic changes. These cycles, however, do not account for the sharp increase in the overall warming trend witnessed recently. Greenhouse gas emissions as a result of human activity have negatively affected the environment and will continue to do so if left unchecked. The potential of global warming and the implications of climate change are fueling the most contentious debates in business, science, and politics. With questions of glacier dissipation, environmental irresponsibility, and the future instability of the planet, world leaders are increasingly more focused on cleaner energy, correcting years of neglect, and ensuring that the amount of greenhouse gases is decreased.
Overall, it is believed that human activity has contributed a great deal towards the climate trends we are experiencing on a global level. Without large-scale buy-in of several of the mitigating actions, the warming will continue and human activity will persist in altering the environment. With current political developments regarding revised Kyoto policies, a more effective and efficient stance by emissions-producing countries and a commitment to re-examining our energy sources, the trends can be slowed and ultimately reversed.