bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using Digital Oilfield Principles to Enhance Safety
Authors: Heckbert Steve , Quick Melissa 
Published: March 2012

Abstract
Chevron has applied digital oilfield principles to enhance workforce safety in emergency situations. An older emergency management process was transformed into a centrally coordinated workflow to guide decisive action and timely evacuation during tropical cyclones.
The Chevron operated Gorgon Project will develop the Gorgon and Jansz-Io gas fields, located within the Greater Gorgon area, about 130 kilometres off the north-west coast of Western Australia. The Project is being constructed on Barrow Island, a Class A Nature Reserve located approximately 60 km off the north west coast of Australia. The environment on Barrow Island is unique. It is home to flora and fauna, some of which are not found anywhere else in the world. Chevron has operated Australia's largest onshore oilfield on the island for more than 40 years, demonstrating that industry and the environment can successfully coexist.
The Gorgon Project is driving significant activity on and around Barrow Island. The construction phase workforce has expanded to undertake offshore drilling and marine operations, plant site preparation, accommodation facilities and aviation support as well as continuing oilfield operations.
The northern coast of Australia, including Barrow Island, is prone to severe tropical storms each season, from November through April. The safety threat is real and unpredictable.
Growth in Chevron's workforce drove a requirement for a well-coordinated storm evacuation process, with unified accountability across the island and offshore vessels. This need was met by developing an i-field decision environment that unites all affected groups, tracks all personnel, coordinates critical data like storm projections and aircraft availability and conserves the safety margin through data-guided decisions, as a cyclone develops and moves.
This transformed evacuation process informs the decisive action that is needed, balancing the paramount need for safety with environmental responsibility and operational goals. This paper describes the results of improved efficiency in demanning safely during storm threats and remanning quickly once the storm threat passes.
(Note: i-field™, the short form of "integrated field", is Chevron's Digital Oilfield program.)
From Standard Operations via Re-manning and Remote Support to Automated Advisory Systems; a Stepwise Development Program for Remote Operations Over a Decade
Authors: Sæverhagen Erland , Thorsen Arve K. , Dagestad Jan Ove , Svensson Inge , Grøvik Lars Olav 
Published: March 2012

Abstract
For anyone involved in organizational changes, people development, optimization of work processes, and reduction in overall risk exposure at the rigsite, the ultimate goal is to develop automation where possible. Automation has been used for years in the car industry, and the oil industry is slowly adopting the potential of automated systems for the drilling environment, gradually integrating all associated processes or important downhole data in full range.
Baker Hughes, with strong support from Statoil, has since 1999 developed a remote operations model based on the Baker Expert Advisory Centre/Operations Network /BEACON) platform, starting with remote operations monitoring from an onshore operations centre. Subject matter experts were placed in the operations centre to process the data in real time, leading to significant changes in work processes both on- and offshore. New positions were developed and new shift plans were implemented. As new downhole tools were developed new service levels such as drilling optimization, ECD management and reservoir navigation services were introduced, all remotely from the operations centre requiring no additional personnel at rigsite, all made possible by rig connectivity, data transfer capabilities and proper work process delineation.
Tomorrow's solution will integrate all available surface and downhole data, and automated advisory systems will deliver advice based on a wider range of combined real-time data, as well as historical databases and best practice, empowering individual judgment and assumptions. This change will significantly contribute to improved operational performance as well as risk mitigation and reduced Health, safety and Environment (HS&E) exposure.
Drilling process automation is something the industry has been anticipating. This paper will discuss the automation potential with respect to remote operations ability, the required development of traditional field positions, collaboration models (e.g., operator/service provider/rig contractor), improved operational efficiency and expectations for operational cost reductions.
Skarv And Valhall Re-development A Journey To The Second Generation Of Digital Oilfields
Authors: Larsen Eldar , Hocking Paul 
Published: March 2012

Abstract
BP in Norway has been in the forefront of developing intelligent energy solutions since 1999 with the installation of their first fiber optical communications link to the Valhall and Ula fields in the North Sea. Throughout the past decade BP Norway has built up considerable experience with Field of the Future Technology ranging from the first advanced collaboration environments for both drilling and operations, the worlds first "Life of Field Seismic" array on the Valhall field as well as advanced remote monitoring tools.
In 2005 it was decided to go ahead with two major projects, one a new field center for the Valhall field and the second a green field development for the Skarv field based on an FPSO. This presented a fantastic opportunity to build on BP Norway's existing experience and create two truly second generation fields of the future. This paper will examine how this was achieved and how the project teams and contractors were engaged via a set of automation and remote performance blue prints to deliver this achievement.
As these fields are commissioned and come on stream they will present a major change in maintenance and operational mind set for the onshore support organization in adopting the extensive remote monitoring and optimization tools that are available to them. New advanced collaborative environments have been provided not only at the main office but also at the new support base and offshore. The Valhall design also includes on onshore control room with full remote control capability.
Clearly these two fields represent a sustainable approach to Intelligent Energy - a world leading example of delivering value retrofitting digital oilfield capabilities to existing assets, then incorporating all the experience and learning into a second phase of greenfield projects.
Connecting a Global Digital Oilfield Community Through a Collaboration Platform
Authors: Coppock Susie , Simonato Ana 
Published: March 2012

Abstract

Description
As large digital oilfield programs evolve, the need to effectively develop and share adoptable solutions across a global enterprise is essential to value realization and solution readiness. The most innovative solutions are typically defined by multi-faceted teams. Once prepared, they must be clearly comprehended by adopting locations. The challenge: How to facilitate the interactions of a geographically-dispersed and functionally-diverse network of petrotechnical, information technology and operations end users, subject matter experts, management teams and central facilitators striving to build a common understanding of new ways of working?

Application
This paper is based on Chevron's experience in leveraging a collaboration platform for the Upstream Workflow Transformation organization that facilitates the adoption of i-fieldSM solutions across upstream business units globally. While it is based on Microsoft® SharePoint® as the technology enabler, the emphasis in this paper will describe the types of global stakeholder interactions, team interactions and information-sharing requirements that can be facilitated through currently-available configurable technologies, and the planning considerations needed for delivering those to a diverse global workforce.

Results, Observations, and Conclusions
The paper will describe results and key insights through this implementation. It will illustrate how a shared virtual home can help facilitate stakeholders' understanding of scope and plans, enable the teamwork of global solutions teams, support design-related interactions, enhance knowledge-sharing across global groups and facilitate resource mobilization, strategies and visioning.

Significance of Subject Matter
Global programs that involve contributors from multiple locations and disciplines will benefit by a virtual location where stakeholders can leverage a shared view to designs, plans, progress and teams can define new solutions collaboratively. Connecting these groups effectively is essential to delivering a comprehensive program built on contributions by all.
A WITSML Enabled Workflow for Integrating Offset Well Drilling Risks and Events Into Well Planning and Execution
Authors: Deeks N. R. , Arevalo Y. I. , Fernandes A. J. 
Published: March 2012

Abstract
In recent years, our ability to record and share information about risks and events affecting rig operations has improved significantly. An important enabler in this has been the development, and broad adoption, of the risk object within the WITSML standard. However, the ability to effectively share data on a broader scale between wells, fields, and blocks has been a challenge. This is particularly important during the planning phase of a well, when access to all available offset risk information is crucial for a successful safe well design.
This workflow, developed within a drilling engineering center, aims to better address this challenge through an integrated 3D approach, using functionality already available on the drilling engineer's desktop. The introduction of a WITSML-based workflow enables efficient and complete data transfer of risk and event data between different users and software applications with the result that the right data is available to the right people, at the right time.
In recent years, our ability to record and share information about risks and events affecting rig operations has improved significantly. An important enabler in this has been the development, and broad adoption, of the risk object within the WITSML standard. However, the ability to effectively share data on a broader scale between wells, fields, and blocks has been a challenge. This is particularly important during the planning phase of a well, when access to all available offset risk information is crucial for a successful safe well design.
This workflow, developed within a drilling engineering center, aims to better address this challenge through an integrated 3D approach, using functionality already available on the drilling engineer's desktop. The introduction of a WITSML-based workflow enables efficient and complete data transfer of risk and event data between different users and software applications with the result that the right data is available to the right people, at the right time.
Drilling risks and events are defined throughout the planning and execution of a well, for example, during surveillance operations within an operations support center or at the rig. Although risk data is generated in predominantly well-centric software, a WITSML server is used to aggregate the data and populate a regional, 3D master risk project. In this project, intelligent filtering and 3D visualization tools are used to target offset data relevant to the current operation. Relevant risks are integrated into a 3D evaluation of the proposed well design, incorporating the geological model of the current prospect. As the well is drilled, the 3D evaluation is used to alert the rig and remote support teams of potential issues ahead of the bit. This approach streamlines the evaluation of risks in the planning stage of wells and enables more effective collaboration between the drilling and geological and geophysical team during execution.
Intelligent Field Management: Real Time Monitoring and Proactive Optimization of Greater Ekofisk Area
Authors: Madahar Amit , McIntosh Alannah , Musatfin Ilnur , McAlonan Nick 
Published: March 2012

Abstract
An online real-time production optimization and monitoring system for the Greater Ekofisk Area of Norway was installed in 2006. The system has evolved significantly since installation; changes driven by multi-disciplinary teams in coordination with the ConocoPhillips Production Optimization Centre (POC).
The POC, Subsurface Production Delivery and Reservoir Optimization teams are tasked with assessing real time data from nominally 160 active producers and injectors in order to minimize losses and thereby maximize field production. This online system integrates data from the complete production system: reservoir to export meters. The system realises the importance of visualisation with respect to monitoring field performance, streamlined decisions, and reduced man hours mining data and analysis. The system allows real time monitoring of all wells and associated instrumentation parameters along with field three phase production allocated to the well level. The system alerts an engineer's attention when a well's performance is outside predefined tolerances thereby enabling continuous optimization of the combined field network.
This paper demonstrates how the online system addresses the following challenges:
Real-time monitoring of separator loadings, production/injection well performance Daily production/injection volume losses allocation Quick screening and allocation issues Generation of updated well models with the latest well test data for further analysis (nodal analysis, lift performance analysis) Generation of updated network models for what-if studies
The tool has an open architecture that allows information to be shared with other software packages. It is also capable of controlling and using results from other software that have open access. The tool is used daily by the POC to review the overall performance of the Greater Ekofisk Area.
Advances in Production Allocation: Bonga Field Experience
Authors: Udofia Emmanuel , Akporuno Mamoke , Vandenberg Frans , Beijer Vincent , Oguntimehen Gbenro , Oni Olatunbosun 
Published: March 2012

Abstract
Bonga field located in deepwater of the Niger Delta in Nigeria, started production in November 2005 and from inception with sustained water injection for pressure maintenance. By 2006, Production Universe which is a state-of-the-art Shell production monitoring and allocation tool was deployed as part of the Bonga Smart Field's Foundation Mark-1 implementation and this has been used for Bonga production allocation process. The Smart Fields Foundation Mark-1 project aimed to provide the Bonga asset with solid data and models for production surveillance and optimisation.
Accurate production allocation has always posed a threat to efficient well and reservoir management in the oil and gas in industry. The traditional approach to production back-allocation to individual wells and reservoir is usually based on ‘one-point’ well test data with the clear assumption that production from this well(s) remains constant (regardless of the prevailing situation affecting this well) for the period of interest. Meanwhile, in Bonga with the support of a real-time ‘virtual meter’ called Production Universe, we have been able to demonstrate significant improvement in our production allocation process as shown in the improved production reconciliation factor between estimated and measured field production data. Bonga is a field with varying flow rates in the producer wells with very fast response to changes in injection rates. Consequently, accurate production allocation significantly improved the Bonga well and Reservoir Management process.
The result of this paper is empirically based supported by data and shared experiences in Bonga field and could be applied in other similar operating assets with the benefit of improved production allocation.
Real-Time Factory Drilling in Mexico: A New Approach to Well Construction in Mature Fields
Authors: Codesal Pablo A. , Salgado Luis 
Published: March 2012

Abstract
In today's economic environment, oil and gas companies are continuously challenged by a combination of ma-turing fields (yielding less while requiring more attention), coupled with increasing human resource scarcity.
This situation is creating higher costs per barrel and changing economic viabilities for development projects around the world. One way to improve economics is to introduce new efficiency gains that reduce non productive time (NPT), reduce well construction times, and, therefore, minimize costs.
The Factory Drilling* approach for field development has demonstrated significant benefits when applied to a well-known field that has consistent well programs and reduced uncertainties. This new way of conducting drilling operations is enabled by real-time data, seamless integration of services, application of suitable technology specific to mature fields, remote operations, multi-tasking of personnel, and fit-for-project rigs. The concept has been successfully piloted in Mexico, on the above-mentioned field, and deployed in twelve land rigs simultane-ously during 2009 and 2010.
This paper describes what was done, how it was done and summarizes key results. Since then, other projects have implemented the same model (with some variations) in other parts of the world.
Design and Implementation of a Global Solution for the Management of Real-time Drilling Data
Authors: Warner Glenn , Hernandez Sergio , Lopez Jesus , Booth Jake 
Published: March 2012

Abstract
Chevron has a longstanding association with the use of dedicated operations centers to support drilling operations. This dates back to the pioneering work of Tenneco in the early 80's, one of a few First Generation Drilling Operations Centers (Booth, 2009). After the acquisition of Tenneco in 1988, Chevron built upon this prior experience in developing a sophisticated support center intended for use throughout Chevron's global drilling operations. As with most of the first generation centers, reduction in drilling activity changed the business case and the strategy was curtailed in 1992. More recently, in 2004, Chevron established a Well Design Execution and Collaboration Center (WellDECC) to support high-cost technically challenging deep water operations in the Gulf of Mexico.
With recent and planned changes in drilling strategies, including the prospect of supporting multiple rig onshore operations both domestic and international, Chevron is embarking on an updated strategy which will institutionalize access to and use of realtime drilling data on a global basis. This includes establishing a central facility staffed by Chevron personnel and operating on a 24/7 basis to monitor the acquisition of data and its integration with technical and operational work processes. This strategy will benefit from the experience derived from the earlier efforts mentioned above. It will also take advantage of significant subsequent advances in information technology and the development and broad implementation of the WITSML industry standard for exchange of data between the multiple parties typically involved in the drilling and completion of a well. This paper describes the strategy's underlying principles and provides information on the design and implementation of an appropriate solution.
Mechanical Diverter in Stimulation Treatments With Coiled Tubing Evaluated With Radioactive Tracers in Carbonate Reservoirs
Authors: Orozco R. Camilo , Melo Narcizo O. , Ulloa J. V. , Robles Hernandez F. 
Published: March 2012

Abstract
Finding new areas to exploit for hydrocarbon production has become a challenge. This has led to wells being completed with more than two or three intervals in different configurations and with various petrophysical properties, which can greatly affect production and also accepting treatment fluids.
In addition, in low-pressure wells with multiple open intervals, conducting effective stimulation treatments using chemical diverters or foamed fluids is not always the best alternative.
For cases with multiple areas, stimulation using coiled tubing (CT) is optimal to help ensure stimulation in areas where new intervals have been created as a result of having previous intervals which had preferential acceptance of fluids.
The purpose of this study is to show how stimulation using CT has evolved from using conventional, rotary, and hydraulic-cleaning tools to the development of a new application for stimulation tools, which helps achieve better placement of acid treatment systems.
The advantages obtained with this new application are Water cut can be reduced with this technique to help ensure intervals near the water-oil contact are not encouraged.It can handle higher pumping rates for effective removal of the damage.Penetration of the stimulation fluids was evaluated using radioactive isotopes, and spectral recordings were taken to assess the depth of stimulated intervals, placement and an estimate of the treatment volume, and the radial penetration of fluids.Fluid flowback is faster, which saves time on installation and introduction of CT for interventions.This acid-stimulation placement technique is the best way to stimulate wells with more than two intervals when selective treatments are required.
Dynamic Well Intervention Modeling
Authors: Newman K. R. 
Published: March 2012

Abstract
A dynamic soft-string finite-element torque and drag model for modeling coiled tubing, wireline and drilling operations in a wellbore has been developed. The model includes the ability to simulate axial and torsional stick-slip for complex dynamic situations such as stall torque, jarring and yo-yoing. This paper documents the equations used to develop this model, compares model results with analytical equations and presents several example simulations performed by the model.