bluuebunny/crossref_metadata_2025_split huggingface dataset:
Methodology For Overcoming Bottlenecks Leading To Successful Implementation of Collaborative Working Environment
Authors: Al Azawi Bahir , Hafez Mohamed , Jakeman Simon , Al Bishr Ibrahim , Bin Amro Ahmed , Malvey Peter 
Published: June 2014

Abstract
While many papers talk about the benefits of Collaborative Work Environments (CWE), few have addressed the issues related to the design and implementation of the projects.
This paper covers the development of the NEB field CWE in Abu Dhabi Oil Company for Onshore Operations (ADCO), and addresses the experiences and learnings across all phases of the project. It addresses the development of the Smart Fields strategy and the planned coverage of CWEs across the producing field, the required IT infrastructure, the selection of applications and the development of workflows to support the CWEs and the significant project management and logistical challenges.
During the course of the project ADCO underwent a reorganization which aligned the company around its producing assets. The paper addresses the benefits that this change has made in implementing the CWE programme and highlights some of the change management issues faced by the team. Critical to the success of the project was to ensure staff quickly familiarized themselves with the new working environment and that a clear support structure was in place which could respond to technical problems and requests for assistance.
A key purpose of the paper is to share the acquired knowledge from implementing the project, covering both the successes and the challenges of overcoming bottlenecks, pitfalls and things that simply go wrong. In such, it provides the leadership practitioner with a balanced methodology of process and necessary soft skills to map out a road which manages the risks and avoids the potholes.
Optical Fibers: The Neurons For Future Intelligent Wells
Authors: Koelman Johannes M. , Lopez Jorge L. , Potters Johannes H. 
Published: June 2014

Abstract
Fiber-optic distributed sensing is known in the oil and gas industry as an enabler for permanent temperature profiling along entire well paths. This application is limited to recovery processes with a pronounced thermal signature. Currently, we witness a confluence of novel fiber-optic technologies promising a much wider and more complete range of subsurface measurements. This opens new avenues in well and reservoir surveillance and highlights the opportunity for fiber-optic sensing to become a pervasive oilfield technology.
In this paper we discuss field trials that combine Distributed Temperature Sensing (DTS), Distributed Strain Sensing (DSS) and Distributed Acoustic Sensing (DAS). These trials demonstrate the potential of fiber-optic sensing technology for well integrity monitoring, gas lift optimization, in-flow profiling and downhole seismic acquisition.
Essential to realizing this potential is the development of cost-effective, easy-to-deploy fiber-optic cables optimized for these combinations of fiber-optic measurements. We also highlight the business integration challenge of handling, storing, and interpreting data volumes that reach levels of 1 TB/well/day. We conclude that while significant technology challenges remain, with a broad range of oilfield technology providers working on derisking fiber-optic sensing technologies, the industry is on the verge of a step change in well and reservoir monitoring capability.
Efficient Use Of High-Frequency Data Through Production Data Management System Implementation
Authors: Creemer A. , Holy R. W. , Fuehrer F. , Mohajer M. 
Published: June 2014

Abstract
The McCully Field (New Brunswick, Canada) is highly instrumented and generates a massive quantity of high-frequency data stored in a data historian. Data time range and frequency of interest had to be manually retrieved through spreadsheet macros for analysis, plotting, and gas allocation. As the production history grew, the amount of data generated was overwhelming and unconsolidated, making the task of manual data handling and visualization both difficult and time consuming.
The implementation of a production data management system resulted in a fully automated, end-to-end workflow that acquires five-minute data from the Supervisory Control and Data Acquisition (SCADA) system into the operating database; performs accurate allocation of gas, condensate and water volumes; as well as creates and distributes daily production summaries to a custom email list in a matter of minutes.
The implementation of an automated approach was driven by five main objectives: automate production data acquisitionoptimize field production through real-time well surveillanceincrease data processing speed (reduce time spent on data handling, preparation, cleansing and reporting)take advantage of existing high-frequency databaseimprove communications regarding well performance between office and field operations
After a successful implementation, data acquisition time has been reduced from a manual 30 minutes to an automated 5 minutes each day. Daily production reports, instead of only being accessible through the server, are now automatically emailed to a distribution list within the company. Real-time well surveillance is now possible from the main office and not only through the SCADA system in the field, which provides the engineering group with a better understanding of individual well performance and also allows any production disruptions to be identified early and resolved efficiently. Finally, the consolidated database is now integrated with engineering analysis tools for further use of information, which ultimately increases the effectiveness of the technical team.
Using Semantic Technology to Auto-generate Reports: Case Study of Daily Drilling Reports
Authors: Giese Martin , Ornæs Jens I. , Overå Lars , Svensson Inge , Waaler Arild 
Published: June 2014

Abstract
The Daily Drilling Report (DDR), a compulsory report to the Norwegian Petroleum Directorate and the Petroleum Safety Authority (PSA) for operators on the Norwegian Continental Shelf, is an example of a task that typically requires integration of data from a variety of independent sources. Current documentation of DDR (EPIM, 2008) content specifies the reporting format in the form of an XML Schema document (XSD), using textual definitions for the explanation of terms.
We report on a case study that demonstrates the use of semantic technologies for the specification, and possibly also generation, of reports in the Oil and Gas sector based on a case study of Daily Drilling Reports. We discuss the underlying vision, present the case study in some detail and evaluate its results. We furthermore discuss the potential of the method for other kind of reports. Finally we conclude with a few recommendations.
Integrated Operations in Statoil - From Ambition to Action
Authors: Lilleng Trond , Øyen Mette , Farestvedt Unn , Engelsen Harald , Nordbø Hilde , Vennes Berit , Revheim Aleksander , Seim Ole , Halvorsen Teresa 
Published: June 2014

Abstract
During 2007 – 2009 Statoil performed a series of steps to enable integrated operations (IO). This included introduction of standardized work processes, a common operating model for Statoil-operated fields on the Norwegian Continental Shelf (NCS) and an IO guideline based on seven IO success criteria, ref. SPE 128576. During 2010 a mapping of IO capabilities based on Statoil's IO guideline and requirements was performed for 28 Statoil-operated NCS fields for selected work process aspects within drilling, production optimization and operations and maintenance. The purpose was to map the degree of IO compliance in relation to the common operating model and identify improvement opportunities within each of the field units.
The mapping was based on a questionnaire of 190 questions and was distributed to 590 persons within the field units. The response to the survey was very satisfactory (79%). To supplement the questionnaire the IO team performed meeting observations and analysis of supplementary data and KPIs for each field. Best practice was identified for most work process aspects and used as a reference for improvements across assets. All the data were treated statistically to limit uncertainties and bias. The mapping project identified IO improvement opportunities within the individual field units, as well as common improvement projects across fields/assets. The paper addresses the challenge of scaling with respect to IO implementation, from selected work processes and individual production installations to broad implementation for Statoil's NCS operations.
The IO mapping project documented the value of utilizing the IO guideline and capability model as basis for identifying actionable improvements with respect to integrated operations in a systematic manner for a large number of assets. The paper describes the method, main results and experiences gained from the project.
A Stack Model and Capabilities Approach to Investigate Integrated Operations Across Different Industrial Sectors – O&G Industry versus Aviation, Military and Medicine
Authors: Larsen Sjur , Bjørkevoll Knut Steinar , Gibson Andrew K. , Gunnerud Vidar , Lien Dag Ola , Thorvik Ketil , Nystad Arild N. 
Published: June 2014

Abstract
This paper adopts a capability and stack model approach to a study of what the oil and gas industry can learn from three selected sectors: military, medicine, and aviation. First, the paper gives an introduction to the stack and capability approach to IO. Next, a preview of common challenges across sectors is provided. Finally, the paper gives examples of cutting-edge developments in medicine, military and aviation, and demonstrates potential learning for the oil and gas industry.
Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field
Authors: Gutiérrez Dubert , Ursenbach Matthew G. , Moore R. Gordon , Mehta Sudarshan A. 
Published: June 2014

Summary
The Morgan field in Canada produces from the Lloydminster and Sparky sands, which are thin heavy-oil reservoirs. Early development of the pool was with primary vertical wells in the late 1970s, with some enhanced-oil-recovery (EOR) projects [e.g., cyclicsteam stimulations (CSSs) and in-situ combustion (ISC)] attempted in the early 1980s. However, the area was essentially noncommercial after the 1986 oil-price collapse. In order to regain commerciality, the operators implemented progressing cavity pumps (PCPs) and horizontal drilling, which have proved to be a success. Even with these advances, though, recovery is estimated to be less than 10% of the original oil in place (OOIP). One of the EOR projects attempted was the combined-thermal-drive (CTD) pilot, which was carried out in one of the sections of the field for 10 years. After a brief primary-production period, the CTD pilot began in 1980 and consisted of three stages. In the first stage, CSSs were performed on individual wells during the first 2 years. In the next 4 years, air was added to the injection stream to perform cyclic air/steam stimulations on individual wells. In the last stage, pressure cycling in-situ combustion was performed for approximately 4 years. In this paper, historical production and injection records were gathered to perform a technical and economic analysis of the project. After approximately 20 years since the shutdown of the project, the data indicate that this pilot has outperformed all of the other operations carried out in other areas of the field. Not only has it produced the largest amount of incremental oil of all the sections of the field, but it also managed to sustain high production rates for 10 years, which is unparalleled in the area. On the economic side, the data indicate that the project was experiencing difficulty because of the 1986 oil-price collapse. However, an economic analysis under current oil prices and costs suggests that it would have been both a technical and an economic success. This air-injection case history represents a good opportunity for those operators facing the challenge to develop thin heavy-oil reservoirs.
A New Model for Reservoirs With a Discrete-Fracture System
Authors: Zeng Fanhua Bill , Zhao Gang , Liu Hong 
Published: June 2014

Summary
Dual-porosity and dual-permeability models for naturally fractured reservoirs assume that the fractures in the reservoir are connected with each other and uniformly distributed. However, in some cases, the reservoir characteristics exhibit a discrete-fracture system, which means that the fractures might be unconnected and their distribution is not uniform. In this paper, a new computational model is developed to compute the transient-pressure behaviour for reservoirs with a discrete-fracture system. This computational model is based on Laplace transforms. The fluid flow in the fracture system and reservoir are computed separately, and flux and pressure equivalent conditions in Laplace space are applied in the fracture wall to couple the fluid flow in both systems.
The results suggest that the pressure response in a reservoir with a discrete-fracture system has three flow regions: fluid flow near the wellbore, fracture-dominated fluid flow, and fluid flow in the matrix away from the fracture. The distance between the fracture and the well, fracture parameters (fracture conductivity and non-Darcy effects), and fracture distribution are the main factors affecting the pressure response. In some particular situations, the fracture-dominated fluid-flow region in the pressure-derivative curve may present two valleys, which has been observed in some field cases (Clarkson 2009). The transient-pressure behaviour of a discrete-fracture system is also compared with that for a composite model. It is suggested that in these two scenarios, the early- and middle-time transient-pressure behaviour may be similar and latetime behaviours are quite different. The model provides a tool for identifying the fracture pattern in a specific reservoir.
Improving Drilling Performance in the Upper Cretaceous: A Case Study From Santos Basin, Brazil
Authors: Flores S. , Fagundes L. , Irokawa Y. , Schmidt A. , Quinones H. , Landinez G. , De Oliveira P.C. , Ramos A. , Medina Y. 
Published: June 2014

Abstract
The Upper Cretaceous is a challenging drilling environment in Santos Basin, offshore Brazil. The lithology consists of highly intercalated layers of sandstone, siltstone and conglomerate from Santos and Jureia Formations. These formations are drilled vertically in 17 ½" intermediate hole and the length of the section varies from 1600 m up to 2000 m. Optimizing the drilling efficiency in this section is crucial to reducing drilling costs and non-productive time.
During a recent exploratory campaign in Santos Basin, severe levels of shocks and vibrations were encountered while drilling this large and intercalated hole section, resulting in a low rate of penetration, premature bit wear, damaged tools, unplanned trips and drill string failures. Three to four bit runs were required to reach section TD.
Post job information and drilling data were reviewed by an integrated operator-contractor team. A detailed engineering analysis of bit, BHA design and drilling mechanics was conducted to address the challenges of this section and propose a new approach to the drilling process. The key was the determination of the best combination of WOB and RPM to drill the different lithologies, together with more stable PDC bits, use of downhole motors and combined with specific operational procedures to mitigate shocks and vibrations.
The proposed changes in bit selection and BHA configuration, drilling parameters and procedures, real-time monitoring and training have been successful. For the first time in the drilling campaign in Santos basin, it has proved possible to drill the 17 ½" hole in one bit run. The section was finished without any incident, under budget and under time.
The improvement in drilling performance achieved with the implementation of this engineering study helped the operator to mitigate shocks and vibrations and save money, thus ensuring a more efficient drilling operation and preventing further drill string failures.
Simulation of Coupled Flow and Mechanical Deformation Using IMplicit Pressure-Displacement Explicit Saturation (IMPDES) Scheme
Authors: El-amin M. F. , Negara A.. , Salama A.. , Sun S.. 
Published: June 2014

AbstractThe problem of coupled structural deformation with two-phase flow in porous media is solved numerically using cell- centered finite difference (CCFD) method. In order to solve the system of governed partial differential equations, the implicit pressure explicit saturation (IMPES) scheme that governs flow equations is combined with the the implicit displacement scheme. The combined scheme may be called IMplicit Pressure-Displacement Explicit Saturation (IMPDES). The pressure distribution for each cell along the entire domain is given by the implicit difference equation. Also, the deformation equations are discretized implicitly. Using the obtained pressure, velocity is evaluated explicitly, while, using the upwind scheme, the saturation is obtained explicitly. Moreover, the stability analysis of the present scheme has been introduced and the stability condition is determined.
Acidizing Sandstone Reservoirs Using HF and Formic Acids
Authors: Yang F. , Nasr-El-Din H. A. , Al-Harbi B. 
Published: June 2014

Abstract
Mud acid, which is composed of HCl and HF, is commonly used to remove the formation damage in sandstone reservoirs. However, many problems are associated with HCl acid, especially at high temperatures.
In this study, formic acid was used to remove carbonate minerals as a preflush and with the main HF stage. A series of formic acid and HF mixtures with different ratios and concentrations were tested. Sandstone cores featured by different minerologies with dimensions of 1.5 in. x 6 in. were used in the coreflood experiments, which were run at a flow rate of 5 cm3/min and temperatures from 77 to 350°F. The cores were analyzed by CT scan before and after the acidizing to investigate the effect of the acid. The core effluent samples were analyzed to determine concentrations of Ca, Mg, Fe, Si, and Al by ICP. 19F NMR was utilized to follow the reaction kinetics and products. Zeta potentials of clay particles (kaolinite, illite, and chlorite) were measured in various acid solutions
Formic acid (9 wt%) damaged sandstone cores. Zeta potential measurements indicated that formic acid can trigger fines flocculation. Addition of 5 wt% ammonium chloride helps to shield negative charges on clay surface. Analysis of core effluent samples indicated that there was CaF2 precipitate in the core when a small volume of preflush was used. Coreflood tests highlighted that formic acid/HF caused loss of core permeability. This paper will discuss the detailed chemical reactions occurred within cores and were followed by chemical analysis of core effluent samples and 19F NMR. Secondary reaction between clay minerals and HF became faster at higher temperature, and decreased the ratio of Si/Al. It was also found that different clay minerals react with HF offering very different concentrations of Al and Si in spent acid.
A Systematic Study of Different Delayed Systems for Mudcake Removal in High-Temperature Horizontal and Multilateral Wells
Authors: Najeeb P. P. , Alkhaldi M. H. , AlFaifi M. G. 
Published: June 2014

Abstract
Effective removal of drilling-mud filter cake during well completion is essential to reduce the formation damage caused by drilling activities in many production and injection wells. This task is very difficult to achieve, especially in horizontal/multilateral wells. Harsh chemical treatments (acids, oxidizers, and chelating agents) have been used extensively to conduct water-based mudcake cleanup treatments. However, these approaches have been limited due to the associated high corrosion rates and un-even mudcake removal. With their controlled reaction with the mudcake, mild chemical nature, better health, safety and environmental (HSE) profile, different acid-precursor systems provide an excellent alternative to harsh chemical treatments in high temperature formations.
This work examines the efficiency of two acid-precursor systems to be used for mudcake removal in horizontal wells. These two acid-precursors (an ester of acetic and formic acid) will generate acid at slow rate at downhole conditions, resulting in uniform mudcake removal. The acid release rate of both in-situ acid generator systems was calculated at targeted average reservoir bottom-hole temperature of 130°F. The study was conducted at simulated reservoir conditions of 500 psi pressure for building the filter cake and 300 psi pressure for soaking the treatment. Drill-in fluids (DIF) sample collected from the field was used for conducting the filter cake removal tests. Return permeability experiments were performed using HPHT filter press cell.
Filter cake removal efficiency of formate ester showed that this system removed 59.3 wt% water-based mudcake formed on a 5 μm ceramic disk when soaked for a prescribed period of 24 hours at 130°F and 300 psi nitrogen pressure. Similarly, filter cake removal efficiency of acetate ester tested on similar conditions removed 30.4 wt% of the filter cake. The break through time for the reactive fluid to penetrate through the mud filter cake was found to be approximately 15 hours for formate ester. Acetate aster system breakthrough was found to be nearly 7 days. Compared to acidic brine (1 wt% HCl), these systems will have slower fluid loss rates where the amounts of collected filtrate were found to be 14.6, 2.7, and 2.5 cm3 for 1 wt% HCl, formate ester and acetate ester, respectively, after soaking time of 2 hours.
Axial Excitation and Drill String Resonance as a Means of Aiding Tubular Retrieval - Small Scale Rig Testing and Full Scale Field Testing
Authors: Forster Ian , Grant Robert 
Published: June 2014

Abstract
This paper describes the work carried out at NOV Downhole on an in house designed and built, small scale, vibration test rig which was developed with the purpose of studying the effect of axial excitation on tubular retrieval.
There are currently well established downhole tools that aid tubular retrieval by way of introducing axial excitation into the drill string fish- with resulting reductions in overpull requirements.
The mechanism for overpull reduction during axial excitation is by way of effectively fluidizing the media surrounding the tubulars and thereby reducing the frictional forces holding them.
By exciting drill string resonances of the fish during the axial excitation process, it is possible for the tubular retrieval fish to behave as a dynamic vibration absorber – a characteristic of which is to increase its response amplitude. This will effectively enhance the fluidizing process.
During the rig testing, it has been possible to compare the Axial Excitation Tool performance at drill string fish resonance frequency with other frequencies. The rig tests demonstrate significant increase in fish response amplitude with the Axial Excitation Tool present at the resonance frequency.
Full scale field operations where an Axial Excitation Tool technology has been applied have resulted in significant overall reductions in overpull.
During the field tests, axial excitation tool and tubular retrieval fish response was intended to be measured and recorded using the black box system. However, this has yet to be achieved, but still remains a future objective.
Never the less, the results for the cased studied so far have validated the rig tests and mathematical modelling.
With reference to offset data, the paper presents actual field data that demonstrates significant reductions in time spent during tubular retrievals, and the corresponding cost savings.