bluuebunny/crossref_metadata_2025 huggingface dataset:
Value of Competency and Value of Competency Assessment
Authors: Nieman Timothy L. , Schuyler John , Brett J. Ford
Published: June 2014

What is the value of a competent engineer? How can we be sure that an engineer is actually qualified? As the big crew change progresses, and as regulators worldwide are beginning to require operators to assure the competency of people working in petroleum operations, these questions are becoming increasingly important. This paper presents an approach to address these questions by looking at competency assurance with probabilistic models.

The value of a competency assessment is demonstrated with a decision tree value of information (VOI) analysis and shows that competency assessments are likely under-utilized. In addition to reducing the chance and impact of defective engineering, assessments provide important feedback to the engineer as learner.

A more detailed model uses Monte Carlo simulation for the stochastic (i.e., probabilistic) calculations, to model training, the design process, and multiple review stages during drilling, completion and production operations. The model uses a competency scale and shows the value of incremental competency improvements. With our judgments the calculations show a dramatic underuse of competency assessment. We further demonstrate how a personal learning initiative can measurably increase competency, and how that competency improves a typical project's value.

The simulation model can help management optimize decisions involving staffing, type and days of structured training, work process design, and design review stages. Added benefits of the modeling approach include tools for individual development, career planning, and organizational learning. We also relate competency and competency assessments to risk management, construction, and safe operations.
Modeling Microseismic Hydraulic Fracture Deformation
Authors: Maxwell S. C , Weng X. , Kresse O. , Rutledge J.
Published: June 2014

Microseismic evidence of fracture complexity has lead to the recent development of new modeling tools to simulate the growth of complex fracture networks. Typically these complex fracture models rely on calibration from microseismic location information, although microseismic source mechanics can also provide additional model verification. Modeled geomechanical deformation associated with hydraulic fracture stimulation of a complex hydraulic fracture provides information that can be compared with observed microseismic deformation. Partitioning of modeled strains into shear and dilatational components allows relative comparison of the appropriate displacement mode with observed cumulative microseismic moments. A number of simple fracture geometries are investigated to illustrate the deformation modes of the modeled fracture displacements. A workflow is also described where the input parameters of the simulation are varied to match both the footprint and deformation of the microseismicity, which then results in an estimate of the complete fracture network volume and proppant placement. In this way the effective stimulated volume can be assessed and used as input to a reservoir simulation to investigate well performance and reservoir drainage.
Assessing the Accuracy of a Production Forecast: West Africa Field Case History
Authors: Apanel Anna , Tester Robert , Thomson Brodie , Mateus Ginga , Marques Gaspar
Published: June 2014

The subject field is located in the deep water off West Africa. Over its 7-year life, the field reached a peak production of 90 thousand BOPD and produced nearly 100 million barrels of oil from a high-quality stacked Lower Miocene deep-water channel complex. This field provides a unique opportunity to perform a look back on how well the reservoir performance predictions made at project funding matched with the final actual field performance.

The West Africa field was a subsea development tied back to a FPSO (Floating Production Storage and Offloading vessel). The production forecast used for project funding was generated using a full field simulation model and optimized depletion plan. The original depletion plan called for crestal gas storage and peripheral water flood. Model properties were derived from a single exploration well and high resolution 3D seismic data.

The production forecast developed at project funding did a very accurate job of predicting average reservoir behavior such as most-likely ultimate recovery and production plateau. However, a more detailed comparison of the pre-production depletion plan and the actual field performance shows significant differences. In particular, both gas and water breakthrough and build up were faster than expected. These factors were offset by higher well productivity and larger in place oil volumes. 4D seismic acquired after 3 years of production was particularly effective in illuminating gas and water flow pathways in the reservoir that had not been modeled or predicted. In addition, changes were made to the original depletion plan to increase recovery and in reaction to operational issues. The factors that drove the evolution in the depletion plan are reviewed and an assessment is made on the accuracy of the original production forecast.

SPE is sponsoring a series of Global Integrated workshops on production forecasting with the objective of assembling guidelines. This paper presents the results of a comparison of a field's production forecast from project inception to abandonment. This example demonstrates that the assessment needs to involve much more than the numerical comparison of predicted volumes versus actual. During the course of field operation, enhancements are constantly identified to increase field recovery as our understanding of the reservoir improves.
Analytical Solutions for Gas Displacements With Bifurcating Phase Behavior
Authors: Khorsandi Saeid , Ahmadi Kaveh , Johns Russell T.
Published: June 2014

Minimum miscibility pressure (MMP) is one of the most important parameters in the design of a successful gasflooding process. The most-reliable methods to calculate the MMP are based on slimtube experiments, 1D slimtube simulations, mixing-cell calculations, and the analytical methods known as the method of characteristics (MOC). The calculation of MMP by use of MOC is the fastest method because it relies solely on finding the key tie lines in the displacement path. The MOC method for MMP estimation in its current form assumes that the composition path is a series of shocks from one key tie line to the next. For some oils, however, these key tie lines do not control miscibility, and the MMP calculated by use of the key-tie line approach can be significantly in error. The error can be as high as 5,000 psia for heavier oils or CO2 displacements at low temperature in which three-phase hydrocarbon regions can exist (L1–L2–V). At higher pressures, the two- or three-phase region can split (or bifurcate) into two separate two-phase regions (L1–L2 and L1–V regions). Thus, for the MMP calculation from MOC to be correct, we must calculate the entire composition path for this complex phase behavior, instead of relying on the shock assumption from one key tie line to the next.

In this paper, the MOC-composition route is developed completely for the bifurcating phase-behavior displacement for pure CO2 injection by use of a simplified pseudoternary system that is analogous to the complex phase behavior observed for several real displacements with CO2. We develop the MOC analytical solutions by honoring all constraints required for a unique solution—velocity, mass balance, entropy, and solution continuity. The results show that a combination of shocks and rarefaction waves exists along the nontie-line path, unlike previous MOC solutions reported to date. We show that by considering the entire composition path, not just the key tie lines, the calculated MMP agrees with the mixing-cell method. We also show that, in this complex ternary displacement, the displacement mechanism has features of a both condensing and vaporizing (C/V) drive, which was thought to be possible only for gasfloods with four or more components. For pure CO2 injection, the solution also becomes discontinuous for oils that lie on the tie line envelope curve. Finally, we show that shock paths within the two-phase region are generally curved in composition space and that there is no MMP for some oil compositions considered in the displacements by CO2. Recovery can be large even though the MMP is not reached.
Tight Hole Spotting in 3D Virtual Drilling Simulator
Authors: Mirhaj S. A. , Oteri V. A. , Sælevik G.
Published: June 2014

It is very important to understand the mechanisms involved during the tripping job and to know about the factors that come into play during and after the tripping operation. There are a number of downhole parameters involved that can interrupt the normal tripping activity and can lead to serious well control situations, such as blow out.

According to estimates in Louisiana, Texas during 1960- 1996, a total of 430 blowouts occurred during drilling, of which pulling out of the hole (swabbing) took the lead with 158 blowouts.

In addition to surge and swab that might come into play, one of the unforeseen problems in tripping job is tight hole that in worse case can lead to stuck pipe and brings about major Non-Productive Time (NPT) of the operation. The causes of tight holes include: Formation related problems (tectonics, etc), borehole trajectory, insufficient inhibition, improper mud weight, lack of lubricity and inadequate hole cleaning.

There are several problems that arise during tripping in/out in the wellbore but emphasis has been placed on tight hole in this study because of high financial impact the drilling industry encounters and downtime it poses during drilling operations.

In this study this challenge that is associated with tripping operations (tight hole) will be implemented in a 3D Virtual Drilling Simulator for a field case in the North Sea and interesting results have been presented. In addition to invaluable results inferred, the 3D Virtual Drilling Simulator can be used to train a complete drilling crew for a specific operation (i.e. RIH & POOH and related challenges).
Geomechanical Analysis to Develop an Extra Heavy Oil Offshore Field
Authors: Gavito Daniel García , Galicia Luis Ángel , García Juan Carlos , Cabrera Ana Corina , Duarte Anna Paula
Published: June 2014

Recent advances in petroleum geomechanics numerical simulations have encouraged industry to invest in finite element simulations to optimize drilling operations. One important part of the drilling process is to understand the rock mechanics behavior, such as deformation and strength through a stress-strain behavior. This work presents the case of study of an exploratory field located at the south of the Gulf of Mexico. This field has two offset wells already characterized by a post mortem 1D MEM (Mechanical Earth Model) study, faults and horizons already interpreted in depth. The principal objective of this study was to develop a consistent in-situ stress state of this field through an in-house finite element program with the help of geoscience analysis & data generation software. The final product of this work will help deliver a consistent stress analysis for the drilling of a planned well in the same field. The rock formation was modeled through a non-linear model. A Mohr-Coulomb with unconfined compressive strength input was used to simulate the formation. The finite element mesh representing the field was fed with elastic and geomechanical properties from the geoscience software, allowing the discretization of the different formations and faults also. Initially this mesh had a size of 74*74*42 and then it was embedded (104*104*62) to let far field stresses act on it. After many simulations the stresses obtained from the simulation were validated against the two offset wells and they showed good agreement. One of the principal variables of this field is the fault structures and how they affect drilling. The 3D geomechanical model concept is a complete process that allows a comprehensive analysis first in loading the grid with mechanical properties, editing the mesh, appending faults, assigning mechanical properties and finally specifying initial stress conditions like stress gradients, directions and magnitudes of horizontal principal stresses and seawater surcharge.
Tight-Gas-Sand Permeability Estimation From Nuclear-Magnetic-Resonance (NMR) Logs Based on the Hydraulic-Flow-Unit (HFU) Approach
Authors: Xiao Liang , Liu Xiao-peng , Mao Zhi-qiang , Zou Chang-chun , Hu Xiao-xin , Jin Yan
Published: June 2014

The crossplot of porosity vs. Klinkenberg permeability (PERM) for 378 core samples, drilled from tight gas sands in the Xujiahe formation of the Anlu region-central Sichuan basin, southwest China, showed that tight-gas-sand permeability cannot be estimated effectively from porosity directly because only a poor relationship can be found between core-derived porosity and permeability because of the strong heterogeneity, especially for reservoirs with dominant microfractures (with porosities lower than 6.5%). However, the problem can be solved by introducing the HFU approach. In this paper, the 378 core samples were divided into five types on the basis of the difference of the flow-zone indicator (FZI), and then relationships of rock porosity and permeability were established for every type of core sample. By virtue of the analysis of the expression of FZI and the classical Schlumberger Doll Research (SDR) Center model, a novel technique used to obtain FZI from NMR logs was proposed and a corresponding model was established. The model parameters were calibrated by use of the laboratory NMR measurements of 54 plug samples taken from the Xujiahe formation. Carried out on the experimental data sets, this procedure can be extended to reservoir conditions to estimate consecutive formation permeability along the intervals through which NMR logs were acquired. The processing results of field examples illustrate that the calculated FZI values from field NMR logs match very well with the core analyzed results; the absolute errors among them are within the scope of 60.15. Moreover, permeability, estimated by use of the proposed technique and the core analyzed results are consistent. However, the calibrated SDR model is exclusive to the cases where formation permeability ranges from 0.2 to 0.4 md. To improve permeability prediction with the SDR model, many more core samples drilled from formations with dominant microfractures needed to be tested for laboratory NMR experiments to calibrate the SDR model for each HFU.
Analyzing The Benefits Of Utilizing 360° Panoramic Photo Survey Technology On A Shell Offshore Platform
Authors: Berger Per Erik , Matsuura Joao Paulo , Barrios Andre , Hopkins Peter , Wagner Marc Thomas , Weston Michael
Published: June 2014

Shell’s Enchilada offshore platform has been surveyed in September 2012 with a specially built, fully automated 100 megapixel 360º HDR panoramic photography camera system with 3D measurement capability. Subsequently, a 360º PanoramicGuide web-based viewer was produced and made available to Shell users. The spherical photos were indexed to the facility’s general arrangement drawings. Interactive descriptive menus and maps were made available to quickly locate and navigate to points of interest. Users can choose from multiple viewpoints of the Enchilada facility, view 360º in all directions around those viewpoints to virtually examine various areas/equipment in the platform, zoom in to view precise detail, and take 3D measurements between visually recognizable shapes and patterns from the viewpoints.

The paper will discuss a number of potential and tested applications, the latter where the technology has been used for the Enchilada platform:

a) Detailed visual assessments for engineering design, project planning, operations and safety reviews; b) Visual reference during conference collaboration meetings with offsite subject matter experts and email communications to assure common understanding; c) Visual assessments by subject matter experts, including consultants and sub-contractors that are not possible with video, standard photography or 3D models/images created from laser scans alone.

Experience using the viewer has demonstrated that users are able to improve quality and collaboration in planning work related to construction and modifications, potentially resulting in decreased cost and project recycle, improved HSE and reduced liability and risk, by minimizing or even eliminating offshore trips and time on site for vendors and other personnel.

Development of new advanced visualization and communication technologies will be a key success factor for future improvements in planning, asset management and Integrated Operations, among other remote operations activities.
Complex Event Processing Implementation for Intelligent-Field
Authors: Al-Bar Abdullah , Gosayir Muhammad , Awadh Waleed , Nasser Nasser , Towaileb Hussain
Published: June 2014

One of the main challenges for Intelligent Field engineers is handling large amount of data stream in real-time. Finding meaningful patterns among this huge amount of data is just like trying to find a needle in a haystack. Every day reservoir and production engineers are being bombarded with streams of massive amounts of real-time data coming from all kinds of Intelligent Field equipment’s including but not limited to Permanent Downhole Monitoring Systems (PDHMS), Multiphase Flowmeters (MPFM), MicroMotion Meters, Wellhead Gauges, Smart Well Completion (SWC), and Electrical Submersible Pumps (ESP). They spend significant amount of time and effort looking at the trends and analyzing the data to find anomalies. Moreover, the existing systems for data cleansing and summarization are based on batch processing, hence, engineers cannot make the right decision on time and they do not have the mechanism to instantly detect interesting patterns in incoming data.

The objective of this paper is to share Saudi ARAMCO’s experience with Complex Event Processing (CEP) as an emerging technology that is design for low-latency and high-throughput event processing for data stream. This paper addresses the architecture, the implementation, and the benefits of CEP as a solution for the Intelligent Field. The implementation will covers three common applications of CEP namely real-time data cleansing, pattern detection, and event driven computation. Data cleansing covers handling out-of-bound, negative, and frozen values. Patten detection enables the detection of anomalous behavior in the data stream, such as unusual buildup or drawdown in well pressure in real-time. Event driven computation is triggered by an event in the field, such as a change in downhole pressure to perform advance calculation logic such as average reservoir pressure. Implementing CEP will help reservoir and production engineers obtain clean data in real time and receive notification in case of any significant event detected.
A Management Framework for Deriving Organisational Cultural Advantage in the Upstream Oil & Gas Industry
Authors: Burridge Glen , Franklin Peter
Published: June 2014

For a capital-­-intensive, high uncertainty and organisationally complex industry such as Upstream Oil & Gas, the imperative of seeking substantive and continuous improvement in organisational effectiveness is strong. One such route is by deploying Cultural Advantage, the basis of which and its importance to the industry we will discuss in this paper.

The literature on the culture of organisations is extensive and consists of myriad models attempting to describe their fabric and explain the collective behaviour which drives them. For the purposes of this paper, we will try to simplify the cultural complexity of every organisation by identifying three main constituent or sub-cultures: NETWORK, NATIONAL and TECHNICAL. All of them influence the organisation and its behaviour and have the potential to pull an organisation away from its strategic goals. However, if they are sufficiently embraced, they may provide a powerful engine for success.

To counter the costly mistakes that may result from poor management of these cultural influences, we outline a number of inter-linked and, in several cases, novel techniques that may be employed at both the organisational scale and within these three sub-cultural domains.

These techniques, we believe, together form a new methodology for Management to address these cross-cultural issues which permeate across our business. Such an approach aims to accentuate the positive potential of the cultural spectrum that exists within every organisation and points the way to illuminating cross-cultural benchmarks that could be applied to any Upstream Oil & Gas entity and provide an engine for greater organisational effectiveness and performance.
Delivering Cost Effective Collaboration Technology Using Consumer Technology and Preparing for a BYOD Environment
Authors: Kirkman Matthew , Hobaishy Hisham , Cobb David , Said Said , Legg Corbett
Published: June 2014

ADMA OPCO’s Digital Oilfield initiative includes the implementation of a collaboration platform across ADMA OPCO facilities, both onshore and offshore, and ready to support both existing and new fields.

Key requirements were an ability to support relatively low bandwidth communication to offshore, a low seat cost, and both desktop and multi-purpose room environments. The ability to simply include third parties was a key issue for the infrastructure choice. Ideally the new system would be compatible with existing standard Video Conferencing (VC) equipment, as well as provide enterprise "Presence", as well as application sharing and control. For the longer term we wanted to ensure we could support the new generation of mobile devices, especially those in common use in ADMA as BYOD (Bring Your Own Device) by employees, and increasingly available in ruggedized and certified form for use in facility environments.

ADMA developed a pilot infrastructure, which included a prototype room design for our New Fields subsurface team, and one of our offshore control rooms, which was invaluable in evaluating recently available technology. The room design initially utilised low cost consumer grade large format televisions, using the TV devices as a switch, and supported the use of 3D Stereo for subsurface model displays, an educational smart board, and a 360 degree camera. The pilot was invaluable in confirming our platform choice, refining the technology (moving to a touch capable large format LCD, rather than the educational whiteboard, and the confirmation of the acceptability of video communication to an offshore control room, as two examples).

ADMA are now in the phase of moving to enterprise deployment of the system, utilising the learning’s from the initial pilot, and adapting to the rapid pace of technology change in this area. The paper will cover the experience of the use of consumer technology for collaboration and key decisions around infrastructure platform selection.
Intelligent Digital Oilfield Implementation: A Case Study of Change Management Strategies to Ensure Success
Authors: Al-Jasmi Ahmad , Goel Harish K. , Cerda Soraya Sirikit , Berry Kevin , Velasquez Guillermo
Published: June 2014

The successful implementation of a world-leading integrated digital oilfield (IDOF) with a national oil company (NOC) required extremely careful and innovative management of the large-scale change required for the project. In particular, the "people side" of that change management was key for embedding the project in the NOC organization and, in turn, making the USD multi-million project a success.

This paper outlines the NOC expectations and describes the steps and processes required to initiate and mobilize the people side of change in the IDOF project and also details the change management challenges experienced before the people- side-focused strategy was determined to be the way forward. Using a simple people-side-focused change methodology not only ensured that the project was successful in terms of return on capital employed (ROCE) but also began the process of ownership and eased the adoption of the IDOF into the current NOC organization. The change management methodology described in this paper was designed to cover and mitigate important challenges that were relevant in driving the people side of change, particularly the following:

WIIFM—"what’s in it for me" scenarios. Culture—the way things are done around here. Success—collaboration, technology leap frogging, people, and oil gains.

This paper describes the main successes, key lessons learned, observations, and progress made against the clearly defined NOC expectations.
An Intelligent Operation Solution for Oil & Gas Production Process
Authors: Hwang Santai , Rodriguez Jose , Healy Justin , Bravo Cesar Enrique
Published: June 2014

This paper discusses the implementation of an intelligent operating system for oilfield processing. It examines the infrastructure of this intelligent software system, from the database backend to the graphical user interface (GUI) frontend. Oilfield processing generally includes the measurement and analysis of reservoirs, controlling oil or gas production flow through the wellbore, risers and manifolds operation, and wellhead operations, then proceeds to the flare point or transportation out from the production facilities. This paper describes how the system can be applied to upper stream oil and gas production management and forecasting. An intelligent solution was used for the research described in this paper. Several sample workflows were implemented for the proof of concepts. The study results indicate that the selected system met all requirements and prove that an integrated and completed system can reduce both human error and operating costs. The system also includes sufficient flexibility to apply to other industrial applications, such as assembly and manufacturing processes.
A Decade Long Journey into Intelligent Field: A Story to be Shared
Authors: Dhubaiki A. A. , Khalifah M. A. , Kaba A. A.
Published: June 2014

Almost a decade has passed since Saudi Aramco implemented its first intelligent completion in a remote area field. Nowadays, the field is the crown jewel of intelligent well completions worldwide, with a large number of inflow control valves (ICVs), a permanent downhole monitoring system (PDHMS), and multiphase flow meters (MPFMs).

This paper summarizes the lessons learned from the assessment and optimization of hundreds of laterals in the field. It also shows how proper ICV utilization leads to production optimization throughout the field. It sheds light on the best practices that helped to realize the full potential of those installations. Finally, the paper ends with recommendations for the way forward and conclusions.

Examples will be discussed in detail to show clearly the benefits and results that could be harvested from the use of intelligent completions. These examples will show some of the benefits that include the revival of dead laterals, controlling undesired fluid breakthrough, and managing sweep efficiency.
A Unified Framework for Implementing Business Intelligence, Real-time Operational Intelligence and Big Data Analytics for Upstream Oil Industry Operators
Authors: Akoum Mohamad , Mahjoub Alaa
Published: June 2014

For the last few years, ADCO has been implementing a program for business intelligence and data management. With the increasing demand for higher production capacity and with the recent evolutions in information, communication and operational technology, ADCO realized the importance of evolving the scope of the program in order to take into consideration real-time operational intelligence and big data analytics initiatives and get prepared to adequately support them. Accordingly, ADCO has established a unified framework for the new program that aims to deliver standardized and integrated solutions for all of the above initiatives. This framework is based on a set of best practices, proven enterprise architecture methodologies, industry standards and reference models. This paper describes how ADCO has selected, combined and tailored the elements of the above set to form a unified framework that suits the overall new program objectives. It also presents the current and future state architectures, and sample use-cases and applications’ outputs.

The above framework can be applied by business and IT architects, strategists and program managers to coordinate and optimize their relevant enterprise initiatives. By early establishing the above framework, ADCO gained more insight regarding the requirements of future phases. Instead of only relying on out-of-the-box operational intelligence applications, ADCO has also considered additional approaches such as self-services analytics to complement them. ADCO identified the need to modify its technology acquisition plans to include new category of tools and equipment. The need for adapting the de-facto standard development methodologies was identified and the framework was tailored to address it. This framework was also tailored to efficiently support big data-requirements. Usingthe above framework realizes better standardization, integration, architecture simplification, dataconsistency and cost-optimization.

Although there are different frameworks that may be used individually to support the above initiatives, the presented framework is a unified way to support and coordinate all of them together.
The Theory of a Fluidic Diode Autonomous Inflow Control Device
Authors: Fripp Michael , Zhao Liang , Least Brandon
Published: June 2014

Traditionally, first-generation inflow control devices (ICDs) were designed to balance completion pressure differential with reservoir pressure differential so that even flow across production zones could be maintained. The purpose of maintaining even flow was to delay influx of unwanted fluids, and thus, help maximize oil production. However, if low-viscosity fluids were present and did succeed in breaking through, a traditional passive ICD could not control the flow, and the unwanted fluid flow would take over. To provide more effective control in these conditions, a newly developed, autonomous Inflow- control device (AICD) has been introduced to theIndustry. This device will improve production by balancing desired production fluids across the completion, while restricting the production from zones with unwanted fluids. This paper discusses 1) how the AICD detects the fluid properties and 2) how the production of the undesired fluid can be restricted without the use of any moving parts.

The autonomous ICD is designed to function without moving parts, without intervention, without electronics, and without control lines. It is a solid-state design with improved reliability, erosion resistance, corrosion resistance, and plugging resistance that can maintain high mechanical integrity. An autonomous ICD operates by detecting whether the production fluid is undesirable, and then, if unwanted, it restricts the production of the unwanted fluid.

The fluidic diode-type AICD operates using a combination of fluid mechanics, computer modeling, and measured performance data, and this paper explains how these devices are capable of restricting undesirable fluid breakthrough without intervention so that a well can continue to produce the desirable hydrocarbon. Testing procedures and results, which include numerical simulation and experimental testing, also will be presented.
Robotics for the Petroleum Industry – Challenges and Opportunities
Authors: Transeth Aksel A. , Schumann-Olsen Henrik , Røyrøy Anders , Galassi Maurício
Published: June 2014

High uptime of petroleum plants, simple logistics, and good Health, Safety and Environment (HSE) conditions are all key factors for a successful petroleum industry. These issues need particular attention when facing new challenges with, e.g., production in more remote areas, but are also highly relevant for many current petroleum installations. Automation and remote supervision and control are both important areas which can address these challenges. To this end, robots are already contributing subsea, but also have the potential to contribute with significant benefits within both the offshore topside and onshore petroleum industry. Such robot technology, often termed offshore robotics, is currently not commercially available and a large scale joint effort is required in order to realize its inherent potential.

Offshore robotics has been a topic of research and development for quite some years and relevant concepts and demonstrators have been developed. However, there are still significant challenges that need to be met in order to take advantage of the opportunities that robots can provide and realize commercial solutions. In this paper, we describe some of the important challenges to be met for enabling this inherent potential. There are both technical and organizational challenges, where the latter include, e.g., building acceptance for new technologies and responsibility issues in connection with remote operations. We also elaborate on key opportunities represented by use cases for robotics within the petroleum industry. A focus is on inspection, maintenance and emergency handling operations. The state of the art on offshore robotics is presented including the activity within this field at Statoil and Petrobras. Successful solutions to the use cases can lead to improved HSE (e.g., fewer people in exposed areas), simpler logistics (e.g., less helicopter transportation), and increased uptime (e.g., through early fault detection and intervention).
Novel Technology for Downhole Reality Check and Realization – A Case Study of Real-time Monitoring of High-Rate Matrix Acid Stimulation Treatments in a Tight Chalk Reservoir using Distributed Temperature Sensing
Authors: Mohamed Hashim A.. , Stemberger D. J. , Mulrooney M..
Published: June 2014

There has been a considerable number of matrix acid stimulation treatments performed in high porosity – low permeability chalk reservoirs in the Danish part of North Sea over the last four decades. During this time, several acid types and diversion techniques have been employed to obtain a desired fluid distribution without the ability to measure the actual success of this distribution. The typical references to design such treatments were based on the knowledge of carbonate dissolution reaction by acid, lab scale core testing and reference outputs of matrix acid model simulators 1. Limited work has been carried out to capture actual dissolution behavior and distribution down the well. This includes understanding both acid-diversion efficiency and production contribution for complex and extended reach intervals.

The implementation of Distributed Temperature Sensing (DTS) and Zonal Downhole Gauges as part of the lower completion in one complex, newly drilled well, has enabled the possibility of monitoring real time temperature profiles along the wellbore allowing determination of flow distribution both before and after an acid and diverter stage enters the formation 2. Realizing the effects of acid and diverters will lead to a better understanding of the chemistry, reaction and diversion process, and subsequently to the optimization of future designs. Fluid flow path and zonal isolation was also monitored during the treatment which provided insights into mechanical issues with respect to tubing, packer, cement and wellbore integrity. In addition to the real-time data gathered during the execution of the treatment, considerable knowledge of post stimulation zonal production contribution was afforded for both production and stimulation modeling.

This paper discusses the benefits, challenges, execution and findings of a complicated application of both DTS and zonal gauges for matrix acidizing treatments and production characterization on an Ekofisk chalk formation. The primary stimulation and the subsequent re-stimulation was executed in opposite ends of the perforated interval with DTS being recorded prior to and after the stimulation fluid was pumped. The captured lessons learned will be an invaluable reference for future acid stimulation treatments of Danish chalk in the North Sea.
A Decision Analytic Approach to Geosteering Operations
Authors: Kullawan K.. , Bratvold R.. , Bickel J. E.
Published: June 2014

The technique of geosteering has been widely adopted in the petroleum industry for proper wellbore positioning. The benefits of geosteering have become more pronounced as drilling environments have become more complex. Geosteering-related technologies, such as downhole information gathering tools, real-time data transmission and data-analysis applications, have been continuously and significantly improved to support geosteering decisions. However, the full value of these advancements has yet to be realized.

Due to uncertainties in predrilled geological models, information gathered while drilling is applied in making real-time reservoir navigation decisions. To achieve an optimal result requires a series of high-quality decisions regarding well trajectory adjustment.

Interestingly, geosteering-related literature does not demonstrate that the industry has applied a logically consistent approach for making geosteering decisions. Common practice as described in the literature does not clearly and quantitatively state measurable objectives, key underlying uncertainties, or relevance between underlying uncertainties and real-time information. Furthermore, it is unclear how a specific geosteering decision is being reached. Lacking of a systematic and transparent framework for supporting geosteering decisions, the current approach is unlikely to result in optimal decisions for placing the well in the best possible location.
Samarang Integrated Operations (IO) - Enabling Real Time Monitoring and Operation of Remote and Mature Asset
Authors: Murugesan K.. , bt Ishak Munira Nur , Bt C Mohamood Nurul Izzwani , Salim Muzahidin Muhamed , Som Mohamad Kasim , Wong Lee Hin
Published: June 2014

Samarang is an existing oil field in offshore Sabah, East Malaysia, developed in 1975. It comprises of 7 wellhead, 3 production, 1 gas compression platforms and 1 Living Quarters. Majority of the platforms are provided with fully pneumatic instrumentation / control and shutdown systems, with no provision for remote monitoring/control except for SMG-A and part of SMDP-A.

Under Samarang Re-development project to increase Samarang production and improve reserve recovery, Integrated Operation (IO) applying real time optimization concept will be implemented.

The main challenges to achieve Samarang IO a real time monitoring and operation environment are as follows: Extensive re-instrumentation work such as installation of electronic transmitters for wellhead and other surface facilities, actuated choke valves for gaslift control, sand monitoring system, downhole gauges & ICVs for smart wells, interfacing with well test meters, operational flowmeters, compressor control panels, instruments associated with separator & crude oil transfer pump etc.Remote Terminal Units (RTU) for the remote unmanned satellites which require certification for Zone-2 hazardous area and weather proof to IP65High reliability and availability designed RTU with dual redundant, hot failover and data buffering up to 5 days.High Availability (HA) data historian configuration with hot failover PI interfaces data collection nodes to enable continuous and uninterrupted surveillance and optimization process.Real time monitoring and control HMI at offshore Central Control Room (CCR), Operation office (SBO) and HQ in a Tri-Node Collaborative Working Environment.The data communication upgrade from remote satellites to mother platform through Wireless Ethernet Radio using TCP/IP-DNP3 protocol; from offshore to onshore (about 55km) through Digital Microwave Radio and leased lines

This paper describes the implementation of Samarang IO key infrastructure – The Real Time Data Acquisition and Control System and underscores its benefits towards achieving real time monitoring and operation.
Second Generation CWE's Can Enable Enhanced Oil Recovery How to add value by deploying CWE's country wide
Authors: Crockett Brian
Published: June 2014

Description

Enhance Oil Recover wells require a greater degree of monitoring and the necessity to respond immediately to anomalies. This is a case study of how a National Oil Corporation moved from one Well and Reservoir Management focused Collaborative Work Environment to a countrywide deployment of eleven CWE’s involved in integrated production system management, monitoring and development of fields moving over to Enhanced Oil Recovery.

Application

To demonstrate how a new design approach to CWE’s permitted Operations teams to use real-time data and exception based surveillance to identify anomalies sooner, maximise the use of collaborative processes and technology to decide faster and ultimately perform better. This paper will explore how a second generation CWE can facilitate collaboration between WRM and Development teams to transition from self-producing wells to EOR wells.

Results

This approach was implemented in Oman across all clusters with Gas lift, beam pumps, Electrically Submersible Pumps, Steam and polymer injection.

The time taken to bring well back to full production was reduced and consequently deferment decreased.

Observations

The following changes in patterns of behavior were observed:

Conclusions

The conclusions can be summarized under the following headings:

Significance of Subject Matter

This demonstrates how a dynamic approach to deployment of a standard solution can be adapted to meet the individual challenges faced by a diverse set of oilfields with a varied Enhanced Oil Recovery strategy.
Drilling Assembly Vibration Model Validated with Frequency Domain Examination of Distributed Downhole Measurements
Authors: Feauto B. l , Jeffery C.. , Hanley C.. , Duff R. G.
Published: June 2014

Resonance is the tendency of a system to oscillate with greater amplitude at specific frequencies. When present in the downhole environment, this effect limits drilling performance. Often, this issue is resolved by employing Finite Element Analysis (FEA) to predict the critical or natural frequencies, which is validated by observing increased vibration levels when rotating at a critical speed. However, this approach is based solely on circumstantial evidence and does not confirm the vibration is occurring at the predicted frequency.

By using multiple Downhole Dynamics Data Recorders (DDDR) in a Bottom Hole Assembly (BHA), the actual vibration frequencies occurring downhole can be calculated and compared to predicted frequencies, thereby validating the FEA model.

This technique was recently used to identify the cause of recurring over-torqued connections in a deepwater application. Analysis of the DDDR data, alongside critical speed modeling, revealed that isolated vibrations within the drill collars were allowing connections to work themselves tighter during specific drilling intervals. These measured vibrations were shown to be resonance-induced by matching predicted natural frequencies with the calculated frequencies from the DDDR, where the observed vibrations increased and decreased in magnitude as the rotation corresponded to the modeled frequencies.

The innovative visualization of downhole vibration data and the validation of critical speed modeling techniques provide a step forward in drilling assembly optimization efforts. These findings will improve the industry’s understanding of critical speed modeling, which in turn will illuminate potential shortcomings of the current methods of vibration mitigation. Practitioners will now be able to design BHAs with more confidence in the results of specific modeling principles, which will ultimately improve performance, reliability and efficiency by eliminating harmful dynamic behaviors.
Improving Resevoir Management through Big Data Technologies
Authors: Seemann D.. , Williamson M.. , Hasan S..
Published: June 2014

It’s time to set a realistic and pragmatic plan for implementing Big Data Technologies so we can revive our vision of Real Time Fields and fully capitalize on them the way we planned all along.

With the introduction of real time streaming data and the resulting data overload, the petroleum industry has effectively entered into the world of "technical" big data. Using traditional data management techniquess on real time data has resulted in data abbiguity and handicaped our ability to understand the information as it flowes through our hands, we are processing more data but less thoughtfully.

Harnessing the power of big data can return us to the concept of diagnose and forecast, enhancing performance, organizations that master this will be capable of responding more rapidly to evolving situations, but success will depend acquiring the expertise.
Real-Time Automatic Operation and Optimization of Produced-Water Treatment
Authors: Asdahl S.. , Rabe K..
Published: June 2014

In general, the operation of produced water treatment systems is often based on manual sampling, visual observations, operator judgment and manual tuning by operation of valves. Work has been conducted to automate the operation of a Compact Flotation Unit (CFU). The objective was mainly to reduce the overall amount of discharged of Oil-in-Water (OiW). As discharge peaks often govern the overall OiW percentage in discharge, a real-time operated and optimized CFU system could immediately detect and reduce the effect of such peaks. Furthermore, the waste generated and utility consumption should both be reduced. The CFU operation would not require operating personnel which is an absolute requirement for an unmanned installation or subsea operation. The work was conducted in a produced water test rig. Manual sampling and visual observations were successfully replaced with online analyzing- and flow measuring technology. This replacement ensured better process overview and allowed implementation of Integrated Operations (IO) philosophy. Advanced control algorithms for real-time CFU operation and optimization were developed based on implementation of this technology. The work has resulted in a new automatically operated CFU system. Testing in the produced water test rig met the goals: increasing OiW content was detected and effective corrective actions were taken without the need for operating personnel. In addition to reducing the OiW content, the waste generation and utility consumption were simultaneously minimized.