bluuebunny/crossref_metadata_2025_split huggingface dataset:
Filling the Experience gap in the Drilling Optimization Continuous Improvement Cycle through a Self-Learning Expert System
Authors: Kirby Cliff , Sadlier Andreas , Wood Christopher , Vinther Morten 
Published: December 2013

Abstract
With deeper and more complex wells being drilled every year to gain access to reserves, experience and knowledge are the keys for minimizing associated risks and reducing costly non-productive time.
Over the last decade, drilling optimization processes and practices have delivered substantial drilling improvements in many different environments worldwide. This has been based on a continuous improvement cycle, consisting of four distinct phases: planning, execution, post-well analysis and lessons learned, which essentially yields personnel experience and knowledge.
Given the current demographics in the oil industry, which is heavily biased towards the 50+ years of age, the "big crew change" is just around the corner. As more and more graduate engineers enter the industry the resulting experience gap needs to be bridged.
Within the controlled environment of the office, graduate engineers are offered guidance and support during the planning phase, however real-time execution requires timely specialist advice and guidance to mitigate drilling hazards. Drilling hazards provide tell-tale signs, and if these signs are captured early, corrective actions can be taken to reduce or completely avoid their impact, reducing operational risk and well delivery costs.
This paper describes an expert system that has been developed to offer immediate guidance to support the delivery of specific real-time specialist advice – based on the system’s self-learning of previous drilling events. The expert system monitors real-time drilling parameters and uses case-based reasoning (CBR) to recognize and capture current incidents that are similar to those that have occurred in the past.
The system can be used to prevent drilling problems before they occur with real-time case-based reasoning for enhanced risk assessment and hazard mitigation. The paper will review examples of packoffs, stuck pipe and lost circulation that have been mitigated.
Produced Water Re-Injection System Optimization: Recipe to Improve Efficiency
Authors: AlKhalifa Hani H. 
Published: December 2013

Abstract
This paper wills discuss in details a technique to improve electric power efficiency of produced water re-injection. Typically such systems are designed with some reservoir performance uncertainties, production demand changes and fluctuation in instantenious flow to through the system. This fact encourages designers and operators to oversize the system to be in the safe side. However, this approach comes on the expense of efficiency of the system (20–30%).
The paper evaluates the existing water disposal system within Upstream Production Facilities at the Ghawar Field in terms of capacity and operations cost and define the required upgrades and areas of optimization. All evaluated plants are conventional Gas Oil Separation Plants where produced water is gravity separated, treated and re-injected back into the producing formation.
The paper will show a step by stem approach to effectively analyze produced water disposal systems and evaluate alternatives to significantly improve their efficiencies and guarantees adequacy. This approach evaluates the whole system from the suction of the disposal pumps to the bottom of the disposal wells of multiple facilities simultaneously. The methodology address reservoir pressure, headers and laterals, pumps configuration and drive mechanism in details. This approach addresses both short and long term optimization needs. In this study the outcome was substantial. Proposed modifications once applied will result into debottlenecking system capacity and improves efficiency to 60–70%. The conserved power was more than 100 giga watts and millions of dollars annually.
The Effect of Noise Attenuation on Data Driven Interpreter Guided Fault Analysis
Authors: Lee Owen , Elghorori Ahmed , Bissett Adrien 
Published: December 2013

Abstract
Prior to any structural attribute analysis on 3D seismic data it is usually necessary to undertake noise cancellation to remove the noise and enhance data quality. We present the results of applying noise cancellation techniques to 3D seismic data and show how that can improve our imaging and analysis of faults. Furthermore we look at automated methods for improving the mapping of major and minor faults using a unique fault workflow.
To be effective volumetric noise cancellation must attenuate noise whilst minimizing the loss of information in order to maintain what is genuine geology. To do this we systematically apply edge preserving methods for attenuating both random noise and high spatial frequency coherent noise that may be masking our true representation of faults. Seismic attributes such as Semblance can then be applied to identify discontinuities within the data which may correlate to structural faults. These types of discontinuity attributes are very sensitive to noise in the data, so running the algorithms on noise attenuated data can have a significant impact on the quality of the result and the scale of the faults that can be interpreted.
Structurally oriented and adaptive filters significantly enhance the reflector continuity and improve lateral and vertical imaging of faults by attenuating higher frequency noise whilst preserving edges.
We will present examples of the effect of noise cancellation on the complete fault workflow from initial attribute analysis to semi-automated fault extraction and analysis, and show the improvements in the fault interpretation with the application of noise attenuation.
Mitigation of Sweet Gas Corrosion in Gas Gathering Systems
Authors: Al-Harbi Mamdouh E. 
Published: December 2013

Abstract
Sweet Gas Corrosion, or CO2 corrosion, is one of the main corrosion mechanisms in oil and gas industry. It results from presence of water containing dissolved carbon dioxide CO2. This phenomenon is influenced by the partial pressure of carbon dioxide, temperature, flow regime and water content.
Over the past few years, concern has grown for sweet gas corrosion in some Saudi Aramco Gas gathering facilities. Severe localized corrosion was noticed in some gas wells piping.
The metallurgy used for surface gas piping is seamless carbon steel in production line spools, flow lines and trunk lines. Corrosion resistant alloy (CRA) is used for the valves to prevent corrosion in the body cavity.
Investigation studies and piping UT surveys were conducted at different areas to assess the severity and extent of such phenomena. Turbulent flow was found to be the major factor for severe sweet gas corrosion in first two spools downstream of wellhead wing valve as well as in spools upstream & downstream of choke valve. Furthermore, insufficient dosage rate of corrosion inhibitor contributed to high metal loss in downstream section of the choke valve in some wells.
Sequence Stratigraphic Modeling Using Outcrop Data in 3D Space
Authors: Sen Gargi 
Published: December 2013

Abstract
Introduction and objective of work
Sequence stratigraphy has grown itself as an extremely useful tip for prediction of lithology and basin architecture in both clastic and carbonate settings. This concept is mostly applied in the Petroleum industries for reservoir prediction using an integrated approach that comprises analysis of seismic, well, outcrop, palaeontological and any other relevant data available. Petrel is widely accepted application hitherto being used for interpretation and reservoir modeling using well and seismic data.
The current work has been carried out with an attempt to demonstrate the use of outcrop data for interpretation of different sequence stratigraphic parameters and subsequently to build a three-dimensional depositional model in Petrel.
The Impact of an Infrastructure Reliability and Data Communication Index on Improving Intelligent Field Operations in an Oilfield in Saudi Arabia
Authors: Velarde S. A. , Al-Ghamdi A. A. 
Published: December 2013

Abstract
Intelligent Field upstream operations in the Oil & Gas industry encompass infrastructure that provides real-time data for monitoring and enabling informed and efficient decision-making leading to improved field operations. Therefore, it is vital to ensure that the infrastructure is reliable and that the data obtained is managed properly to make it available to end users. This paper proposes an integral approach to measure Intelligent Field Infrastructure (IFI) and data communications reliability and explains its applications and reachability on field performance.
This innovative method supports engineers to tackle issues in timely manner. In addition, a robust IFI optimizes production strategy by exploiting available data to improve well rate compliance, monitor well integrity and reduce field surveillance activities. Furthermore, a reliability index requires a consistent asset inventory supported by an effective maintenance strategy that is perceptible to all involved organizations.
Six sigma methodology tools are to be implemented to address reliability. To conduct a root-cause analysis leads to identify the flaws in data communications and infrastructure. Then, data is to be compiled within a process mapping structure that can be used to generate performance plots ranked upon Failure Mode and Effect Analysis (FMEA). Building a reliability index powered by visualization tools lead to expose hidden areas of opportunities to improved field operations. This integrative approach provides different organizations with one platform to overcome reliability issues and reduce equipment downtime; hence, maintaining asset value and capitalizing its capability.
The approach presented in this study is relevant to Oil & Gas industry professionals involved in IFI for understanding the impact of asset integrity on remote operations capability. It also sheds light on understanding the role of information-driven analytics on optimizing field performance.
Vertical Cased Producers Outperform Horizontal Wells in a Complex Naturally Fractured Low Permeability Reservoir
Authors: Widjaja Danang R. , Lyngra Stig , Al-Ajmi Fahad A. , Al-Otaibi Uthman F. , Alhuthali Ahmed H. 
Published: December 2013

Abstract
This paper is a case study for a complex highly fractured low matrix permeability reservoir. The material presented demonstrates that understanding the fracture influence on reservoir fluid flow is essential for successful development and reservoir management of this type of naturally fractured reservoir. Several well examples are offered illustrating the paramount importance of completion strategy with increased reservoir maturity to enhance matrix oil recovery and minimize natural fracture network water production.
The case study reservoir was initially developed with a small number of vertical cased, perforated and stimulated producers produced at a restricted total off take rate and pressure supported by peripheral water injection. The next development phase was the drilling of single lateral horizontal producers completed open hole with approximately 1 km of reservoir contact. In earlier stages of production, both vertical and horizontal well completion types performed well as the natural fractures were oil filled.
As water moved towards a structurally higher position due to natural fracture system depletion, the open hole completions became a major water production source. Subsequently, a revision of the well completion strategy was required to minimize the water encroachment through the fracture system with the intent to maximize matrix oil recovery and also resolve well lifting problems. This paper presents the production performance review that followed after recompletion of the existing open horizontal wells with perforated liners or special equipment, such as stage stimulation completions.
The production performance data from the recompleted horizontal wells are compared to well production performance of the original and some newly drilled cased, perforated and stimulated vertical producers. In this case, it is apparent that simplicity wins and the vertical well solution is the optimum well strategy for future development.
Application of Fast-SAGD in Naturally Fractured Heavy Oil Reservoirs: a Case Study
Authors: Sarapardeh A. Hemmati , Kiasari H. Hashemi , Alizadeh N. , Mighani S. , Kamari A. 
Published: December 2013

Abstract
Steam injection process has been considered for a long time as an effective method to exploit heavy oil resources. Over the last decades, Steam Assisted Gravity Drainage (SAGD) has been proved as one of the best steam injection methods for recovery of unconventional oil resources. Recently, Fast-SAGD, a modification of the SAGD process, makes use of additional single horizontal wells alongside the SAGD well pair to expand the steam chamber laterally. This method uses fewer wells and reduces the operational cost compared to a SAGD operation requiring paired parallel wells one above the other. The efficiency of this new method in naturally fractured reservoir is not well understood. Furthermore, how operational parameters could affect the efficiency of this method is a topic of debate. In this study, Fast-SAGD is compared through numerical reservoir simulations with standard SAGD in an Iranian naturally fractured heavy oil reservoir and additionally some operational parameters including initiating time of steam injection in offset well, number of cycles assuming the same total period of steam injection, offset injection pressure, elevation of offset well from the bottom of reservoir and vertical distance of production and injection SAGD well pairs have been evaluated in Fast-SAGD process. The operational parameters have been optimized based on Recovery Factor (RF) and economical points. The results of this study demonstrated the exceptional performance of Fast-SAGD process in naturally fractured reservoirs and the RFand thermal efficiency of Fast SAGD are enhanced tremendously comparsed to SAGD. In addition, the results indicated that the most important parameters that should be optimized before Fast-SAGD is initiating time of steam injection in offset wells. This study reveals improved efficiency and lower extracting costs for heavy oil in naturally fractured reservoirs applying Fast-SAGD process. Also it is indicated that optimization of operational parameters significantly improves Fast-SAGD performance in such reservoirs.
Reservoir Quality Impact on Identifying Unayzah Prospective Areas in Abu Dhabi
Authors: Al-Zaabi Mohamed R. , Taher Ahmed A. 
Published: December 2013

Abstract
Reservoir quality in the Unayzah is largely controlled by depositional environment early clay diagenesis, burial- compaction and quartz cementation. Present day reservoir quality can be predicted by modeling the porosity evolution of simplified model rocks with representative depositional and early diagenetic attributes through their burial history.
In Abu Dhabi Unayzah fluvial sands are predicted to have consistently low reservoir quality due to poorly-developed, early grain coats that have allowed abundant quartz cement to form. In the Unayzah C, open fractures observed in fluvial samples may provide useful high permeability streaks within these intervals. Fluvial sands are predicted to have higher porosities in areas with low thermal maturity, where quartz cementation would be less advanced.
Unayzah sandy sabkha reservoir quality is predicted to be uniformly poor as a result of fine grain size, poor sorting, and early diagenetic clays that filled pores. Unayzah Aeolian sand quality is variable, depending on the type of clays in pores. A zone of infiltrated clay coats is observed in well H-1. this zone is characterized by clean, effective macroporosity, resulting in good permeabilities and low connate water saturations. Below this zone, all Unayzah aeolian sands contain diagenetic clays. Where finer grain size or poorer sorting results in small pores, the diagenetic clays bridge much of the porosity and significantly reduce effective macroporosity. However, in well-sorted, coarser-grained dune sands, pores are large enough to be lined but not filled with diagenetic clays.
Reservoir quality prediction approach is based on conceptual model of sandstone porosity evolution, with burial derived from observation in multiple reservoirs. In this model, the main controls on the pore system evolution are mechanical compaction and cementation.
Terrestrial Wireless Broadband Enables Smart Drilling
Authors: Al-Lawati Ali 
Published: December 2013

Abstract
This is a presentation on how wireless communications can enable smart drilling in the oilfield, and the benefits that oil and gas companies can realize from smart drilling procedures enabled by wireless communications.
The concept of the digital oilfield is an oilfield that is connected from end to end. It’s an oilfield where all devices, all people, and all assets are tracked, monitored, and can participate in a joint collaboration that is the operation.
These benefits can only be realized with a ubiquitous network that covers the oilfield from end to end, and enables last mile connectivity for activities like wellhead automation, level field connectivity, operational video surveillance, micro seismic applications, asset tracking via RF-ID and Wi-Fi-RD, energy management, collaborative working environment, and all the collaboration tools that this entails, and, of course, smart drilling. The location, geography and distances associated with most oil fields require that the network be wireless, and new advances in wireless technology have now made this vision real and affordable.
We’re going to look specifically at smart drilling, the benefits that smart drilling brings to the operation as a whole and how wireless communications is especially well positioned to enable smart drilling in today’s enhanced oil recovery oil and gas operation.
The promise of enhanced oil recovery can be realized when new techniques and new technologies allow us to recover oil that in the past we were have been unable to extract. With enhanced oil recovery, additional extraction is possible, safely and quickly.
Framework Model Building in Highly Complex Structures Utilizing Multi-Azimuth 3D Seismic Data: Case History from Bahrain Field
Authors: Maili Eduard , Hoffman David , Al-Tawash Feras 
Published: December 2013

Abstract
The workflow discussed in this paper shows the process of building a complex fault framework using wide-azimuth seismic and abundant well data. 3D fault interpretation using azimuthal seismic volumes allows for subtle fault detection and better fault definition. Using special workflows which "snap" seismic faults to the well fault cuts, we illustrate how to build, and quickly update a very complex structure framework with a high level of accuracy.
The Bahrain field is a salt-cored, elongated and almost N-S anticline, with multiple oil and gas reservoirs in formations of Paleozoic, Jurassic, and Cretaceous age. Structural deformation has been nearly continuous from Triassic to early Tertiary, with a complex growth and deformation history (Samahiji and Chaube, SPE 1987), resulting in a highly-faulted structure with compartmentalized and fractured reservoirs. Therefore, building an adequate structure framework model is critical for the new development of this field, where over 250 wells per year are being drilled in various reservoirs.
The existing 3D seismic survey in Awali field was acquired in 1998. Though it was intended and initially processed as a narrow azimuth volume, it has been recently reprocessed in wide azimuth mode using new and advanced processing technology (Maili et al, EAGE-Copenhagen, 2012). This advanced processing was made possible by the particular acquisition geometry (cross spread with 8 receiver lines live), allowing for wide azimuth data in the upper part of section where many of the key oil producing reservoirs are located.
This new approach to structure framework building using automated workflows described here allows rapid framework updates to be made with data from newly drilled wells, and makes it possible to shorten the cycle time for geologic model building and maintain an "evergreen" model. This up-to-date structure framework also plays a key role in operations for planning new wells and drilling following-up.
From Empirical to Micro-scale Modeling of Multiphase Flow; Bridging the Gap of R&D
Authors: Al Qahtani Abdullah , Al Sultan Abdullah , Hadhrami Luai 
Published: December 2013

Abstract
In the petroleum industry, multiphase flows are complex phenomena and can be found in a variety of situations. The three more common working fluids (oil, natural gas and water) can have four different two-phase flow permutations of the three types of fluids. Multiphase flow modeling/metering is a key factor for optimal flow design and realizing optimal recovery of hydrocarbons. Over the last few decades, scientists developed the math of pressure and flow rate relationship in multiphase flow. A number of empirical correlations and mechanistic models have been developed for predicting pressure drop and other fluid flow characteristics during multiphase flow in wellbores and flow lines. Similarly, the emerging sensing and measurement tools were adapted for application of multiphase flow in oil and gas fields. With all calculation being computer-assisted and after many years of development and experimental research, the computer based numerical analysis methods have been evolved to solve the large number of equations and correlation coefficients. With the vast application of high performance computing, computational time is not an issue anymore but accuracy.
The challenges associated with multiphase flow modeling/metering include accuracy, size, application, and cost. The need for efficient and cost effective modeling/measurement systems in oil and gas fields have kept and will continue the need for active participation of R&D and better integration with sensing systems.
This paper reviews the state of art of modeling of multiphase flow and the major headways that led the way for subsequent research in this regard, and potential ways to promote accuracy and reduce cost. These are potential research projects being evaluated / proposed in the research institute in King Fahd University of Petroleum & Minerals in collaboration with international service providers and national field operators.