bluuebunny/crossref_metadata_2025_split huggingface dataset:
Short Radius Horizontal Sidetrack into Sandstone Reservoir and Completion with Inflow Control Device & Zonal Isolation-A Case Study
Authors: Shastri Mukesh Chandra , Gazi Naz H. , Kotecha RohitKumar , Al-Enezi Hamdah , Al-Azmi Khalid Humoud , Gilani Syed Zubair , Saradhi Vijay , Vijayvargiya Vivek , Al-Sabea Salem 
Published: March 2015

Abstract
For managing limited resources, short and medium horizontal sidetracks offer feasible options for non-conventional well work-over. Sidetracking into horizontal lateral is preferred over other options due to improved productivity.
Many short-radius horizontal sidetrack wells with high Dog Leg Severity (DLS) have successfully been drilled and completed with Inflow Control Device (ICD) in carbonate reservoirs in the Middle East, however in case of sandstone reservoirs it poses a great challenge.
This technology, which envisages short and medium radius horizontal sidetrack from existing well bore for optimal utilization of asset, was applied in a sick well from Greater Burgan field in Kuwait. A window was cut in existing 7″ casing and 6 1/2″ drain hole was drilled up to 6016′ MD. Initially this well was planned for sidetrack into main sand with maximum 35° DLS and feasibility study was done. But due to mechanical complications during work-over it was kicked off shallower, cutting shale above main sand, and the final well trajectory was maintained with maximum 23° DLS. The horizontal lateral was completed with 4 ½″ ICD and seven numbers of mechanically set open-hole packers for zonal isolation.
The well completion with this technology with high DLS in a sandstone reservoir is probably the first time in the world. This paper will describe and present the case history of the application of this technology; the challenges faced during work-over, drilling of the drain hole with sand-shale contrast and the smooth running of completion assembly with high DLS.
After work-over the well was put on production in May'08. As on date it is flowing with 45 -55% water cut which is almost constant since then, resulted in a net gain of 2400BOPD from this well. This successful sidetrack leads to more applications for exploiting heterogeneous reservoir in the Middle East Region.
Management of E&P Data using Enterprise GIS System
Authors: Puripanda Naresh Kumar , Kumar K , Anaisi Abdulla Al , Prasad Vineet , Sowayed Mohammed 
Published: March 2015

Abstract
Exploration and Production industry over a generation of time have invested heavily on G&G, Production and Engineering data and their relevant applications. The whole data is generated and utilized right across the business value chain however; many organizations struggle to manage their data effectively and how well this vital geographical information is integrated and analyzed can be critical to the success of any organization.
Petrochemical giants have embraced GIS as a means of detecting oil and gas resources and tracking oil spills. At its core, GIS is a visual database that is transactionally updated. It makes use of data creation workflows that harness the underlying database, using it to produce different views depending on what users want.
Bapco has established an Enterprise GIS System (Bahrain Petroleum Company's (Bapco) Integrated E&P Digital Oil Field) which helps in accessing, monitoring, analyzing, organizing and managing data related to all aspects of Bapco's business units in an effective manner. This is one of the main gateways to a wide range of E&P data and is much more than a visualization and analytical tool. It is highly secure, strongly integrated and coupled with many of the Exploration & Production databases and applications. This system facilitated preparation of the roadmap for better petro-technical data and information management initiatives, particularly to control data that are extensively volume-driven as is the case with seismic, well logs, production, geological and reservoir simulation models and time-critical or real-time data. One can use GIS to map anything and to combine anything mapped with further data to see the patterns. GIS helps change how we think and behave. People see things differently, and this enables them to approach problem-solving in new ways.
This paper discusses the approach adopted by Bapco in managing E&P data using Enterprise GIS System.
Horizontal Reentry Wells in Khafji Joint Operations: From Unachievable to a Benchmark of Success
Authors: Al-Fawwaz Abdullah , Muheeb Mohammed , Osman Ahmed , Al-Ghazzawi Ayman , Al Fakih Abdulqawi , Azher Mohammed Mushtaq 
Published: March 2015

Abstract
Khafji Joint Operations (KJO) is operating a key oil-producing field. This field has been developed extensively via horizontal drilling technologies for the past two decades. With excessive time and costs required for new offshore structure installation, the utilizing of the existing wells to drill re-entry horizontal wells became imperative and economical solution for further field developing, while minimizing the cost per foot required for well delivery.
Horizontal Re-entry operation in KJO has always been deemed totally undoable due to the fact that the 7 inch production liner in most of the old wells was tied back and cemented to surface. Hence, re-entry sidetrack operation would not have enough conventional casing strings options to allow the drill ahead to reservoir while having enough mechanical barriers to isolate the unstable shale zones. Also, slimming down the well design could not be a favored option as it does not accommodate the geo-steering, formation evaluation and completion requirements; which are essential for placing and producing the re-entry wells within KJO reservoirs.
To enable these re-entry wells, the Khafji drilling teams have performed a comprehensive study and risk assessment to re-define the strategy for drilling these horizontal re-entry wells. The new strategy divided the targeted re-entry wells into three main categories based on the challenges and complexity underlying each well. Each category was then assigned key enabling technologies in mud, drilling systems, optimum drilling practices, and completion techniques. These strategies along with enabling technologies were successfully implemented in a new horizontal re-entry campaign in KJO and have managed to deliver eight of these challenging wells during years 2013 and 2014.
Novel Technique for Reciprocating Compressor Cylinder Leak Detection
Authors: Hastings M. , Koop L. 
Published: March 2015

Abstract
The polytropic exponent function is an existing proprietary monitoring function that automatically detects reciprocating compressor cylinder leaks. It uses dynamic pressure and corresponding calculated volume values at, for example, one degree intervals, to calculate the polytropic exponent value of the measured compressed and expanded gas within each cylinder end. Deviations of this calculated exponent compared to the known polytropic exponent of the gas properties gives an indication of a cylinder leak due to a specific valve, the seal, the piston rings or even a crack in the cylinder liner. A non-proprietary version of the polytropic exponent function has been developed and tested on a gas re-injection reciprocating compressor and it can lend itself to be further refined to make it more independent of the gas properties.
The need for reliably detecting reciprocating compressor cylinder leaks is paramount as the cylinder, and more specifically the valves, account for the majority of the maintenance. PV plots are often used to determine cylinder leaks but these currently cannot be easily monitored to alarm limits automatically and require specialists to analyze and interpret the results. Moreover, the gas properties are also needed to generate theoretical PV plots that can be compared to the actual plots and there are many installation errors that can “distort” the PV plot. The polytropic exponent function provides automatic monitoring capability without requiring much specialist expertise, but it is still currently a proprietary solution and requires intimate knowledge about the gas properties. This paper focuses on the refinement of the existing polytropic exponent function.
The new refinement is currently being tested on a gas re-injection reciprocating compressor at an offshore project. No leaks have been detected up to now, but results show a stable, reliable function that is well suited to monitoring applications, although with limitations.
Completion Optimization for Unconventional Reservoir
Authors: Hamid Osman , Rahim Zillur , Alshakhs Munther , Mubarak Ahmed , Fisher Kevin , Ba-wazir Omar A. 
Published: March 2015

Abstract
The success in producing from unconventional reservoirs is made possible by horizontal drilling and reservoir stimulation through multi-stage hydraulic fracturing along the laterals. Although hydraulic fracturing techniques have been widely used for unconventional shale gas stimulation, a considerable percentage of perforations do not contribute to production. Reservoir characterization and computation of completion parameters are essential for effective completion design to improve staging and perforation placement.
Challenges in hydraulic fracture design are the proper placement of fracturing ports or perforations and location of isolation packers due to the large variability of fracture gradient, mechanical and reservoir properties, and petrophysical characteristics existing along the lateral. Industry experiences show that injection pressures required to fracture the formation (fracture gradient) oftentimes vary significantly along a well, and there can be intervals where the formation cannot be fractured successfully by fluid injection due to the existence of high in-situ stress.
Geomechanical and Petrophysical evaluations providing rock anisotropy and anisotropic stress properties along the wellbore play a fundamental role in completion and hydraulic fracture design. In this paper, geomechanical and petrophysical properties from open-hole logs and sonic anisotropy evaluations have been integrated to compute reservoir quality and completion quality. Intervals with similar properties are then grouped in a manner to better understand and optimize hydraulic fracture design and operations. This procedure is applied in a borehole within a potential shale-gas reservoir targeting the hot shale facies formation in Saudi Arabia resulting in a successful completion optimization and hydraulic fracture performance.
Novel Insights into Mechanisms of Oil Recovery by Low Salinity Water Injection
Authors: Sohrabi M. , Mahzari P. , Farzaneh S. A. , Mills J. R. , Tsolis P. , Ireland S. 
Published: March 2015

Abstract
The underlying mechanism of oil recovery by low salinity water injection (LSWI) is still unknown. It would, therefore, be difficult to predict the performance of reservoirs under LSWI. A number of mechanisms have been proposed in the literature but these are controversial and have largely ignored crucial fluid/fluid interactions. Our direct flow visualization investigations have revealed that a physical phenomenon takes place when certain crude oils are contacted by low salinity water leading to a spontaneous formation of micelles which can be seen in the form of micro-dispersions in the oil phase.
In this paper, we present the results of a comprehensive study that includes experiments at different scales designed to systematically investigate the role of the observed crude oil/brine interaction and micelle formation in the process of oil recovery by LSWI. The experiments include; direct flow (micromodel) visualization, crude oil characterization, coreflooding, and spontaneous imbibition experiments. We establish a clear link between the formation of these micelles, the natural surface active components of crude oil, and the improvement in oil recovery due to LSWI. We present the results of a series of spontaneous and forced imbibition experiments carefully designed using reservoir cores to investigate the role of the micro-dispersions in wettability alteration and oil recovery. To further assess the significance of this mechanism, in a separate exercise, we eliminate the effect of clay by performing a LSWI experiment in a clay-free core. Absence of clay minerals is expected to significantly reduce the influence of the previously proposed mechanisms for oil recovery by LSWI. Nevertheless, we observe significant additional oil recovery compared to high salinity water injection in the clay-free porous medium. The additional oil recovery is attributed to the formation of micelles stemming from the crude oil/brine interaction mechanism described in this work and our previous related publications. Compositional analyses of the oil produced during this coreflood experiment indicates that the natural surface active compounds of the crude oil had been desorbed from the rock surfaces during the LSWI period of the experiment when the additional oil was produced.
The results of this study present new insights into the fundamental mechanisms involved in oil recovery by LSWI and new criteria for evaluating the potential of LSWI for application in oil reservoirs. The fluid/fluid interactions revealed in this research applies to oil recovery from both sandstone and carbonate oil reservoirs.
Detecting and Correcting Pipeline Leaks Before They Become a Big Problem
Authors: Cramer R. , Tulalian R. , Angelo P. , Van Stuijvenberg M. , Shaw D. 
Published: March 2015

Abstract
Timely pipeline leak detection is a significant business issue in view of a long history of catastrophic incidents and growing intolerance for such events. It is vital to flag containment loss and location quickly, credibly and reliably, for all green, brown field critical lines in order to shut down the line safely and isolate the leak. Pipelines are designed to transport hydrocarbons safely; however, leaks have severe safety, economic, environmental and reputational effects.
This paper will highlight robust, reliable and cost effective methods, most of which leverage real time instrumentation, telecommunications, SCADA, DCS, and associated online leak detection applications.
The purpose of this paper will be to review the underlying Leak Detection business issues, catalogue the functional challenges and describe experiences with available technologies. Internal and External techniques will be described, including basic rate of change of flow and pressure, compensated mass balance, statistical, real time transient modeling, acoustic wave sensing, fiber optic cable (distributed temperature, distributed acoustic sensing) and subsea hydrophones. The paper will also describe related credibility, deployment, organizational and maintenance issues with an emphasis on upstream applications.
The scope will include leak detection for pipelines conveying various flowing fluids – gas, liquid and multiphase flow. Pipeline environments will include subsea and onshore.
Advantages, disadvantages and experiences with these techniques will be described and analyzed.
Predicting Water Movement Using a Discrete Fracture Network Approach Combined with Fluid Flow Modeling in a Naturally Fractured Carbonate Reservoir
Authors: Jambayev A.S. , Todd Hoffman B. 
Published: March 2015

Abstract
Predicting the movement of fluids in large naturally-fractured carbonate reservoirs is challenging because of the many uncertainties such as complicated fracture networks and the heterogeneity of carbonate rock; however, flow models are necessary to understand and predict reservoir behavior. In this paper, we study one such reservoir where there are concerns with the potential for very high water production.
A well from this reservoir was suspended due to water cut (up to 60%) shortly after putting it on production, and there is concern that the water seen at the well might end up at nearby wells. The objective of dynamic analysis is to predict potential water flow from the aquifer through the fractures to two other producing wells.
A three well section of this reservoir is studied by combining a discrete fracture network (DFN) model with a finite difference flow simulator. Fracture parameters such as intensity, size, shape, and orientation are assigned to each fracture based on measured data or relevant statistical distribution derived from the measured data. Well test results, using the constructed DFN models and the results of actual test, are used to determine skin and fracture permeability. The DFN model is then upscaled to obtain grid properties including porosity, permeability and sigma factor suitable for a dual porosity flow simulation model.
Many different scenarios are simulated with different water influx rates and different DFN models, which show the wide range of water breakthrough times (16 to 161 months) and cumulative produced water volumes (8,000 to 1,000,000 bbl), however the largest impact on the results is the aquifer strength. We recommend further testing the shut-in well to try to estimate the influx potential, so a more accurate prediction can be made for breakthrough time and produced water volumes.
The workflow presented in this paper allows for building representative models of fracture networks, which can improve reservoir characterization, flow predictions and reservoir management strategies.
Implementation Study for Miscible Water Alternating Gas (WAG) EOR in a Giant, Offshore Field
Authors: Al Shehhi Budoor , Patel Harshad , Jani Zankar , Khan Sameer 
Published: March 2015

Abstract
The WAG (water-alternating-gas) recovery process is a well-established process for enhanced oil recovery with several successful field applications. This process is evaluated for potential application in a giant, offshore Abu Dhabi field. This paper describes an evaluation approach of the WAG process application to the subject field.
Many separate reservoir simulation models were created to evaluate various aspects of the WAG recovery process. The models addressed WAG operating parameters such as implementation timing, and the effect of WAG parameters (WAG ratio, cycle length). The models were also used to estimate the rate and recovery impact of WAG implementation using different injectants (off-site available hydrocarbon gas, associated gas, enriched gas).
The evaluation process for the giant field started with a small 3D sector model derived from a full-field model of the most significant reservoir unit. This model was extensively used to test the operational parameters. The findings were then tested with larger-scale models for full-field evaluations. Finally, grid sensitivity studies were done using 2D cross-sectional models to calibrate the recovery results from the coarser gridded full-field models.
Results show that WAG incremental recovery over the waterflood recovery for the situations studied is about 7 to 8% OOIP (original-oil-in-place). A WAG ratio of 4:1 appears to be optimal. Incremental WAG recovery is insensitive to cycle lengths and timing of WAG implementation. Miscible injectants provide higher recoveries than immiscible gas injection. Model derived recovery benefits were sensitive to the grid size with as much as twice the likely benefit shown with a coarser grid.
Innovative Permit to Work System - HSE Management in Engineering Manner
Authors: Xingchen ZHOU , Zhang William , Harm David , Jianhua GONG 
Published: March 2015

Abstract
This paper summarizes the successful practice of applying an innovative Permit to Work (PTW) system that has immensely improved the HSE performance of PetroChina Southwest (PCSW).
This system demonstrates how the ‘line’ organisation can effectively and efficiently manage HSE along with its production responsibilities. It has been developed in line with the project management process; organically incorporating Hazard and Effect Management Process (HEMP) principles.
This system differs from a traditional one in term of approaches, roles and responsibilities. Its built-in mechanisms facilitate 100% quality PTW/Job Hazard Analysis (JHA) preparation, precise implementation in the field and continuous improvement of mindset, technical competency and work attitude of staff and contractors.
It has established ‘Best in Class’ JHAs and best practices for quality PTW/JHA preparation, system isolation, gas testing, toolbox talk, verification of safe work conditions, and PTW effectiveness assessment.
Initially developed by the principal Author in 2007, the system was then assessed by the Shell Group Risk and Assurance Manager to be “outstanding and worthy of sharing and adoption more broadly across Shell operations” 1during a global HSSE&SP Audit in October 2008. Its main contents have been introduced to the current Shell Group Permit to Work Manual.
This system has helped a Shell/Sinopec JV to achieve 9 Million Man Hours without Lost Time Injury and 3170 “Goal Zero” Days to the date of 15th October 2014. The Sinopec Group has enforced this system to other ventures. Dozens of Shell coal gasification licensees have adopted it as well.
The current PTW process was updated by its developer in 2012, based on the 2007 version. This new version crystalized upon the successful Shell-PetroChina HSE Cooperation Program. Applying the new PTW system, PCSW has recorded its best HSE performance in their history. Its parent company, PetroChina intends to roll it out across the Group.
Ultrasonic High Resolution Real Time Thickness Combined With High Resolution Multi-Sensor Caliper and CBL Tools in a Single Pass: New Mechanical Well Integrity Logging String Identifies Difficult Casing Problems
Authors: Tello Lucio N. , Lopez Eglee Y. , Azuaje Dimas C. 
Published: March 2015

Abstract
Ultrasonic scanning tools measure the casing thickness by inducing a mechanical resonance of the casing in the thickness mode. At the same time they measure the cement acoustic impedance at higher radial and vertical resolution than sector and segmented tools. A modified Multi-sensor caliper tool measures the casing ID with excellent accuracy and resolution.
A DFT algorithm implemented in the ultrasonic radial scanner tool improves the circumferential and vertical coverage of the thickness over previous methods while widening the measurement range, resolution and accuracy. The algorithm is performed by the tool with more circumferential coverage of the pipe than before. The tool performs this in real time at normal logging speed, thus saving operation and rig time.
When the new ultrasonic radial scanner tool is combined with the new multi-sensor caliper, the magnetic flux-leakage tool, and the CBL in one pass, the tool string generates data that identifies casing damage otherwise difficult to detect with just one of the tools. In addition, the ultrasonic cement impedance measurement and the CBL-VDL (in combination) identify clearly the cement bond conditions. This combination provides comprehensive well mechanical integrity interpretation of the well.
New 3D visualization capabilities of caliper, magnetic flux-leakage, and ultrasonic measurements provide the operator with information to interpret broken or parted casing. This 3D visualization also provides critical information after the remedial work is finished. Discerning whether there is internal or external damage is important information for the operator.
The capability to identify previously undetected casing damage corroborates the new high resolution real time thickness methodology and the improved multi-sensor internal caliper measurements. The four tools in combination provide a valuable method for identifying difficult casing problems.