bluuebunny/crossref_metadata_2025_split huggingface dataset:
Smooth E&P Activities in a Remote Area Having Fragmented/hostile Communities Around - A Case Study Highlighting How an E&P Company Made it a Reality
Authors: Khan Murad Ali 
Published: June 2014

Abstract

Description of the Paper
This paper shares the experiences and results that eni Pakistan had by adopting a ‘Community Investment Management System (CIMS)’ in a developing country -Pakistan. CIMS philosophy is to make ‘Community Relations’ and ‘Community Investment’ management an integral part of the overall business fabric. This system was evolved taking into consideration full E&P activities life cycle in context of indigenous culture, traditions, customs and environment of local communities living around.

Applications
CIMS utilizes the logic of project life cycle, highlighting the importance of stakeholders and company’s risk assessment in ‘Context Analysis’ and adopts the ‘Logical Framework’ approach to plan, manage, monitor and evaluate the interventions.
eni Pakistan has done so by development of people & promoting the indigenous culture, establishing mutually benefitting relations with all stakeholders, fully respecting the territory and the society of which it is an integral part.

Results

Conclusion
Smooth running of E&P activities can be supported by adopting ‘CIMS’ process that can deliver same results anywhere in the world should applied with true spirit and commitment.

Preamble
Over the years E&P Companies around the world have experienced the fact that if local community (living around the areas where E&P activities are conducted) issues are not addressed timely and effectively it gives rise to vulnerable situations that are very challenging to handle and manage. This delayed or no addressing of local community issues aids in development of a culture of distrust among E&P Company and various local community stakeholders. This distrust aggravates the situation and aids in making it a monster to manage. These vulnerable situations sometimes push viable E&P projects into a deadlock scenario with local communities making them unviable. Even in this situation if the interface with local communities are managed by deploying heavy security on ground, the E&P projects remain vulnerable as local community starts behaving in a hostile way with the E&P Company.
Key to transforming this situation into an opportunity is to engage local community into a participatory role by proactive and timely addressing of their real needs and issues. eni Pakistan Ltd has been successful in making this transformation into reality by proactively handling local communities that are living around their Bhit/Bhadra Development Leased Area. This proactive handling of Local Communities have ensured smooth running / continuity of eni Pakistan E&P activities on-ground. Objective of this paper is to share details of how eni Pakistan utilized this opportunity in achieving this success.
Development and Field Trial of a New Exploration HPHT Reservoir Drill-in Fluid
Authors: Færgestad Irene M. , Watson Russell , Strachan Cameron , Johannesen Jorunn 
Published: June 2014

Abstract
The newly developed high-temperature high-pressure (HPHT) exploration oil-based reservoir drill-in fluid (RDF) was specifically designed with formation damage, pressure logging and geochemical analysis in mind. Requirements for a reservoir drill-in fluid that performs well under HPHT conditions, has good pressure log response and is geochemically distinguishable from reservoir fluids were the driving forces for the development of this system. The high-performance, low-damaging system combines several new products. Laboratory results have shown good rheology profiles, tight HPHT fluid loss control, high return permeability values and excellent long-term fluid stability. The system was developed to replace today's standard paraffin systems which occasionally struggle with irregular and too high viscosities with poor fluid stability over time. This occasionally leads to various drilling issues and barite sag problems during low shear or static conditions. Laboratory testing has documented the qualities of the new system, followed by a very successful field trial, where low impact on geochemical tests was obtained. This paper details the development of the fluid, the testing performed to qualify it for the field trial and the successful results from that field trial. Furthermore, the paper also details the high return permeability values and the mechanisms within the system that allow these goals to be achieved. The fluid has properties that make it an extremely strong candidate for reservoir drilling in general.
Some Effects of Size Distribution on Particle Bridging in Lost Circulation and Filtration Tests
Authors: Gatlin Carl , Nemir Charles E. 
Published: June 2014

Introduction
A common cure of lost circulation is the introduction of granular bridging agents into the mud system. Many materials, such as ground nut shells, are used for this purpose. If the trouble causing void (fracture, fissure, vug, etc.) is not too large, the granular agent forms a "bridge" across or within the opening. Successively smaller particles in the mud stream then accumulate on and/or within this bridge until normal filtration is finally established. The efficiency of many bridging agents has been studied in the laboratory using various slot testers.
Many investigators have remarked that a granular bridging material should have the proper particle size distribution. With the exception of the broad range specified in the patent of Goins and Nash, there is apparently no definition as to what this distribution should be.
A bridge may be initiated when several particles of lost circulation material lodge against each other in a fracture or other void. Smaller particles then may bridge the openings between the larger, previously bridged particles. This process continues until the voids become quite small and the problem becomes one of filtration. It would seem logical that an optimum particle size distribution exists, i.e., one containing the proper quantity of properly sized material to fill the successively smaller voids of the bridge.
The filtration characteristics of drilling fluids may be subject to a similar analysis. It has been clearly demonstrated by many workers that the filtration behavior of various muds can be altered by particle size control. Slusser, et al, divided filtration into three periods and showed that particle sizes affecting a given period did not necessarily affect other portions of the filtration curve.
An analagous problem is the proper sizing of gravel, liner slots and screen sizes in various sand-exclusion problems. Here the situation is reversed in that a proper "void" size, rather than the size of the bridging agent, is sought.
An Explicit and Continuously Differentiable Flow Equation for Non-Newtonian Fluids in Pipes
Authors: Gjerstad Kristian , Ydstie B. Erik , Time Rune W. , Bjørkevoll Knut S. 
Published: June 2014

SummaryA simple model approximates Herschel-Bulkley (HB) non-Newtonian fluids in laminar flow in pipes. It is continuously differentiable and explicit in the frictional pressure gradient. Such properties are needed for control, real-time optimization, and prediction in drilling operations. The accuracy of the new model is evaluated by comparing it with a numerical implementation of the implicit HB model and some representative approximations used in the literature. Very little loss in accuracy is experienced compared with the implicit solution.
Case Study—Equivalent-Circulating-Density Management Strategy Solves Lost-Circulation Issues on Complex Salt Diapirs/Paleocene Reservoir
Authors: Murray David , Sanders Mark W. , Houston Kirsty , Hogg Hamish , Wylie Graeme 
Published: June 2014

Summary
Drilling horizontal infill wells in the Pierce field in the UK Central North Sea (UKCNS) is challenging because of the narrow drilling window caused by depletion in a highly fractured reservoir, which is complicated further by water injection and the proximity of other production wells. Wellbore strengthening was attempted in the reservoir section of Pierce B5 (B5), although, when a pre-existing fracture weakened further by depletion was encountered, losses occurred. During the next 10 days more than 5,000 bbl of nonaqueous fluid (NAF) was lost downhole. During the recovery from the losses event, 15 individual treatments with lost-circulation materials (LCMs) were made. More than 50 t of LCM was used without success; however, the well was stabilized enough to secure the drilled footage and to complete the well.
Two additional horizontal wells in the same field were successfully drilled with a low-equivalent-circulating-density (ECD) management strategy combined with the development of a low-ECD drilling-fluid system and the use of a high-fluid-loss, high-strength (HFHS) pill. The dual problems of barite sag and poor hole cleaning, which can be problematic when reducing ECD through a reduction in fluid rheology, were successfully managed. This low-ECD technique can be applied in other subsea depleted wells in which a narrow drilling window exists.
This paper describes how a detailed analysis of the losses event on Pierce B5 provided an improved understanding of the loss mechanism that resulted in a revised ECD-management strategy. An engineered low-ECD NAF with an HFHS pill, combined with learnings on ECD awareness in the planning and execution phases, mitigated the drilling risks on subsequent wells. This has implications when encountering very large fractures that are difficult to overcome, not only on future Central North Sea wells, but also globally for wells drilled in similar geological settings.
Maturing Collaboration in Intelligent Energy: Challenging the Conventional Wisdom of Collaboration Environments
Authors: Kuhn Michael 
Published: June 2014

Abstract
Maturing Collaboration in Intelligent Energy: Challenging the conventional wisdom of Collaboration Environments This paper explains why the conventional wisdom of collaboration environments is out of date with the current landscape of technology enablers and should be aligned with the shifting landscape of how people collaborate.
To date, the collaboration has focused on enabling team collaboration. The focus going forward should be to enable the Digital Engineer and move away from designing collaboration environments around structured team processes, as this actually limits the value of the collaboration environment. After years of significant investment in collaboration technology, process improvements and change management, many organizations have not captured the transformational value that was promised with such programs. Common themes have emerged from industry case studies to better understand the root causes associated.
A Collaboration Maturity Model was introduced in a previous paper (Gilman, Kuhn 2012) to outline the current state of collaboration and potential future areas of innovation. The underlying enablers of collaboration will be discussed such as technology; environment, process and organization that have shifted to suggest the traditional team based collaboration environments do not fit the expectations of today’s Digital Engineer. Many of the traditional collaboration environment designs were focused specifically on enabling teams to work together when information could not be easily shared and communication across distance was not seamless.
Today there is a clear opportunity to re-think collaboration environments to better meet the work practices of next generation workers.
Development and Implementation of an Effective Operator Interface System in the UAE
Authors: Legg Corbett , Kirkman Matthew , Al Gaith Saud , Ali Kamal , Tysseland Trond , Dalloul Naseem 
Published: June 2014

Abstract
ADMA-OPCO have maintained a consistent Operator Interface System (OIS) in the control rooms over recent decades. The need to move to a modern interface compliant with current industry best practice for three major new field projects was recognized in 2009 in the new projects specifications. This addresses both safety and efficiency while recognizing the increased level of instrumentation on the newer facilities and the expected diversity in our future workforce.
Developing a new OIS approach required working with vendors to ensure the ability to technically deliver the new design regardless of vendor. There was also a review of current practices by other international operators. The new design addresses past OIS deficiencies in the graphics imposed by limitations of older systems used to monitor, control, and respond to events in the process. Those deficiencies were in colour, content, layout, and difficulty in the maintenance of operational settings. Much time was spent in control rooms eliciting input from current operators, both experienced as well as recent hires.
The new specification utilizes pattern recognition techniques to easily verify a stable process state from massive amounts of data and addresses the appropriate use of colour and patterns to quickly direct attention to areas of concern. This OIS emphasizes a logical and consistent schematic layout based on process and operational divisions. The operator adjusts target values and alert limits allowing monitoring and maintaining the process in an optimal state before supervisory set alarm limits are reached.
Prior to implementation in the new fields, the OIS was implemented as a pilot in parallel with the existing system on a portion of the Das Island processing facility. This was to capture lessons and input from operators using the new system before finalising the new fields design with an alternate vendor. In parallel, a campaign was undertaken to eliminate nuisance alarms and to adjust instrument ranges and supervisory alarm limits to more appropriate levels.
The evolution of the operating design philosophy and the process for design, engagement, and implementation from those activities through the initial pilot system start up are discussed. The system described below is now formalized as an ADMA standard procedure, and will be implemented by the Main Automation Contractor on ADMA New Fields.
Building Neural-Network-Based Models Using Nodal and Time-Series Analysis for Short-Term Production Forecasting
Authors: Rebeschini J.. , Querales M.. , Carvajal G. A. , Villamizar M.. , Md Adnan F.. , Rodriguez J.. , Knabe S.. , Rivas F.. , Saputelli L.. , Al-Jasmi A.. , Nasr H.. , Goel H. K. 
Published: June 2014

Abstract
Implementing asset-wide intelligent digital oilfield (iDOF) solutions, aiming to optimize oil and gas production system in an "intelligent" manner, requires integrating concepts from different disciplines, such as artificial intelligence. Neural network- (NN-) based models are a form of artificial intelligence, which is a branch of computer science that generates mathematical models that can be "trained" to determine relationships between inputs and outputs, recognize patterns, and perform reliable short-term predictions. NN models using real-time data are proven tools for short-term well production forecasting with acceptable accuracy.
An oilfield is a hostile environment for even the most robust instrumentation. As a result, technical outages or anomalies can result in lost or poor quality data. Experience shows that many samples in a real-time database are frozen, missing, corrupted, or incorrect. This fact represents the biggest challenge to creating a reliable NN model. However, the models can be trained to correct or estimate missing real-time data. This paper presents a case study where nodal analysis was used to populate missing data used to train NN model, thus improving the reliability of the model. Because nodal analysis is not suitable for prediction, time-series analysis was used to assess the impact of historical events, and operational conditions were used to forecast trends. The NN trained with nodal analysis can cover a wide variability spectrum and, when trained with a time-lapse series, can predict short-term (30-day) production scenarios by changing highly correlated parameters, such as tubing head pressure (THP) or frequency (Freq).
This paper describes training NNs using nodal analysis and time-series analysis to predict short-term water cut (WC or BS&W) and liquid flow rate. This technique was applied in over 20 wells with electronic submersible pumps (ESPs) and gas lifts (GLs). The NNs made robust estimates of production rate and an acceptable prediction trend for 30 days, even when confronted with flow meter instrumentation failure, lost signals, and out-of-calibration instruments. Hence, the NN served as a "virtual meter," providing instantaneous and accurate estimation of production data.
South Oman Progressing Cavity Pumps Continuous Control Pressure Setup
Authors: Al Mahrooqi Salim , Velazco Conny , Vargas Luis , Sanchez Carlos 
Published: June 2014

Abstract
In fields with large number of wells, any improvement in the monitoring and production optimization processes can have a significant impact in the overall field performance.
With this vision, in April 2012, a new tool for optimizing PCP wells was introduced in PetroleumDevelopments Oman (PDO) as a trial. This new setup was based on enabling Pressure Control Setup (PCS) control that would allow the PCP speed to be adjusted based on well/reservoir potential assessedby a measurement from a downhole pressure gauge. The downhole pressure value is used as target value for this PCS controller.
This paper describes the main benefits about implement a PCS loop after implementation in two pilotPCP wells based on intake pressure. This setup enhances well operation by timely maximizing production and/or accelerating production optimization, protecting the pump against running dry and protecting the reservoir should a lower pressure limit be reached, e.g.a limit that can onset sand production or water coning.
An additional benefit of using this tool is the reduction of the required manpower which also reduces the HSE exposure due to less mobilization and traveling time, for the well optimization.
Real-Time Optimization of a maturing North Sea Gas Asset with Production Constraints
Authors: Van Der Linden Ruud , Busking Tom 
Published: June 2014

Abstract
As gas and oil fields mature their operation becomes increasingly more complex, due to complex process dynamics, like slugging, gas coning, water breakthrough, salt or hydrate deposition. Moreover these phenomena also lead to production constraints in the upstream facilities. This complexity asks for operator support in how to optimally operate such an asset.
In this paper we explore how, based on physical models of reservoirs, wells and top side separation and compression equipment, real-time optimization may be used in optimal operation of a maturing asset showing complex dynamic behavior and top side compressor constraints. In a joint industry project of Wintershall, GDF, EBN, Siemens and TNO the applicability of Real-Time Optimization is explored.
Real-time optimization will be demonstrated on a maturing North Sea off-shore gas production asset consisting of eight wells and two separator and compression trains.
The current results show how the optimization problem has been defined and implemented in a real-time architecture. First results are shown realizing the gas production set point and minimizing compressor power, while the production of individual wells suffer from degrading performance and (unplanned) shut-ins.
The optimizer computes how the production must be dynamically distributed over the wells and how the compressor trains must be operated.
Dynamic optimization strategies have been exploited successfully in downstream operations. A similar development is happening in upstream industry, while having to cope with the higher uncertainties typically present in upstream processes. As the paper shows Dynamic Optimization may lead to large benefits in Real-Time Operation of upstream production facilities.
Smart Mobile Worker- Bringing our Facilities closer!
Authors: Van Dijk Jaap E. 
Published: June 2014

Abstract
Today, production of oil and gas is faced by many challenges as the major sources become depleted. This leads into the exploitation of remote and inhospitable fields of deep water reservoirs, frigid arctic climates and for PDO hot dusty deserts. To maintain the highest possible production at these harsh operating environments, whilst meeting the challenges of personnel safety, lower operating costs and preserve environmental protection, forefront technologies are required to explore new ways of reducing the need of people to be in hazardous areas, and improve their productivity, safety and efficiency while onsite.
Smart Mobile Worker (SMW) provides the capability of "Remote-expert" mode between site staff and technical experts where experts anywhere in the world can be easily and immediately confronted with problems. Further, SMW introduces a new step change by delivering real time information to workers anywhere on site enabling them to make more informed timely decisions by bringing the right data resources and knowledge anywhere onsite.
The SMW concept is an essential shift towards realization of smarter sites by increasing field workers efficiency & productivity, and improving HSSE to achieve Goal Zero. Primary focus will be on Smart Sites because remote work is fundamental driver here.
This Manuscript describes a first pilot in the field where the focus was on SMW 1 Audio & Video functionality. It explains the use of this new technology in an operational environment where by with a minimum investment of time and money has delivered 50% improved production on one specific well. Also a significant improvement in efficientcy and reduction of HSE exposure was recorded. To underline SMW benefits we can show a trial video or live demo depending on some technical boundaries at the conference location.
Achieving Digital Oilfield Competency
Authors: Pickering J. G. , Sengupta S.. 
Published: June 2014

Abstract
Many oil and gas operators now see Digital Oilfield as a mature technology and yet there is still a broad spectrum of knowledge across the industry about what it is and how to derive a good return on investment. Much has been said about developing the "People", "Process" and "Technology" sectors in parallel but even the most enthusiastic Digital Oilfield adopters would admit that it is the "People" sector that gives them the greatest challenge. The big problem is how you engage the entire workforce, from senior managers to field technicians, in a technology with which only a few are really "hands on". Many companies have chosen to ignore this problem and yet the entire workforce must be engaged, as the senior managers will be the financial decision makers and the field technicians will be the enablers of real-time data.
This paper describes a novel approach to training and the achievement of real Digital Oilfield competency. It reviews typical delegate responses to more traditional classroom learning versus innovative styles based on learning through enjoyment, including participation in business games and role playing.
The authors have experience of different training styles but have found that creating a less formal atmosphere with a high level of personal engagement and active participation delivers the best results. They are now proposing an "a la carte" approach to training, through a range of course modules that may be tailored to the requirements of the delegates. So, in effect, the delegates choose up front what they want to learn. The course must deliver a foundational knowledge of Digital Oilfield but may have a technical, commercial or even a cultural focus to satisfy the requirements of the delegates, who must be matched carefully to ensure that they have the same training expectations.