bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluating the Performance of Intelligent Completions
Authors: Yadav Varun , Surya Neha 
Published: March 2012

Abstract
In the last decade, evaluations, discussions, workshops, and sharing of experiences have helped increase the number of intelligent well system (IWS) solutions being installed around the world. The intelligent wells offer many advantages over conventional completions. These primarily range from accelerated production, increased recovery, reduced or eliminated intervention, and improved reservoir performance. A second set of factors that need to be considered range from reliability of system, overall complexity, contingency operations, and economics.
Instead of a large number of IWS being installed, many questions remain on the performance of these completions. Some of the concerns are lower return than expected/predicted, risk of valve failure affecting well integrity and uncertainty as to the most effective future operational practices.
This work reviews several typical intelligent well systems (IWS) completed, including a gas producer, oil producer, auto-gas lift oil producer, multilateral IWS producer, and horizontal openhole multi-isolation producer. For each case, the wellbore modelling, completion design, choking operation strategies, and estimated performance will be introduced. In conclusion, this paper will show how modelling technologies were developed to derive the IWS well and equipment design. It will cover lessons learned through our experience in intelligent well systems, including flow modelling, erosion analysis, tool selection, and crossover control, and how we expect the future movement of this technology to evolve.
Early Symptom Detection Based on Real-Time Evaluation of Downhole Conditions: Principles and Results from several North Sea Drilling Operations
Authors: Cayeux Eric , Daireaux Benoît , Dvergsnes Erik Wolden , Sælevik Gunnstein 
Published: March 2012

Abstract
During drilling operations, downhole conditions may deteriorate and lead to unexpected situations which can result in significant delays. In most cases, warning signs of the deterioration can be observed in advance, and by taking proactive actions, drillers can avoid serious incidents like pack-offs or stuck-pipes. A new analysis methodology, relying on an automatic real-time computer system, has been developed to detect those early indicator conditions.
The methodology comprises constantly computing the various physical forces acting inside the well (mechanical, hydraulic and thermodynamic). These physical forces are coupled by an automatic model calibration, which then gives a reliable picture of expected well behavior. Through analysis of the deviations between modeled and measured values, an estimation of the current state of the well is derived in real-time. Changes in the well condition are an early warning of deteriorating well conditions. This paper describes precisely the real-time analysis and the results during some drilling operations.
The software has been used for monitoring fifteen unique wells located in five different North Sea fields. All major situations were warned in advance at different event time scales: rapidly changing downhole conditions (such as pulling a drill-string into a cuttings bed) were typically warned 30 minutes ahead of the actual event, medium duration deteriorations were detected up to 6 hours before the incident, and slow changing downhole conditions were signaled up to 1 day in advance. Several examples that illustrate the detected incidents over distinct time periods are described.
The availability of good quality real-time data streams makes it possible to implement such analysis tools in an integrated operation setup. Early symptom detection can be used to take decisions in a timely fashion, based on quantitative performance indicators rather than subjective feelings and personal experience.
Interoperability, a Paradigm Change
Authors: Montgomery Ronald L , Favilla Jose R. 
Published: March 2012

Abstract
Description: Industrial Capital Project Engineering Design solutions are heavily dependent on large scale custom integration services efforts to hand over key information to the Operations and Maintenance application environment. Individual Owner/Operators must each redundantly bear the development and sustaining costs for these efforts. Large engineering design suppliers offer proprietary ecosystems making their own rules for technology enablement often setting high costs and onerous technology prerequisites. Often these artificial rules require owner operators to choose systems based on suboptimal criteria or worse require them to rip and replace existing systems. These barriers and artificial guidelines lock owner / operators into proprietary applications with very high initial costs and high ongoing costs. A new engineering data handover and ongoing operations and maintenance sustaining model is proposed in this paper advocating an Open Standard "system-of-systems" approach for engineering, operations and maintenance information. This Open Standards approach recommends an Interoperability Solution rather then custom service delivered "point-to-point" integration strategies for the general industry engineering eco-system. The Open Standards Approach is based on open, supplier neutral standards, enabling initial loading and incremental update of participating systems eliminating custom service based integration.
Application: IBM has been collaborating with industry standard bodies and key standards based suppliers like Assetricity LLC bringing proven Interoperability functionality. This approach enables enterprise service bus integration neutral exchange of information leveraging a standards-based common engineering register coupled with a reference semantic information abstraction model that provides a safe, reliable and replicable roadmap for interoperability. The solution has been adopted by several oil and gas companies as a basis for enterprise information exchange.
Conclusions: An IT design framework is offered for integrated operations and maintenance for oil and gas companies that is architecture centric, product neutral, operating platform neutral, enterprise service bus neutral, enabled by standards at all levels, supported with a practical implementation approach.
Significance of Subject Matter: The creation of a reference semantic information model and an Engineering Register based on in-depth understanding of industry standards coupled with Open Operations and Maintenance Web Services provides the establishment of a safe roadmap for interoperability that enables a industry paradigm change that significantly reduces the cost of initial information handover and sustained information change management for the Engineering, Operations and Maintenance environment for both the Upstream and Downstream and Process Unit Operations in general.
Building Capacity for Innovation - A Drilling Contractors Approach to Continuous Change Management
Authors: Eike Martin 
Published: March 2012

Abstract
This paper presents how a drilling contractor based on the Norwegian continental shelf has increased efficiency and reduced NPT through a systematic approach towards continuous change management. In close collaboration with their customers, they have transformed their operational model through increased use of data-sharing, continuous support, and knowledge transfer. A qualitative case study of the change process revealed that the successful implementation was secured through:
The presence of an overall organizational structure giving room for innovative thinking and development of new ideas, while at the same time having a hierarchical and communicative structure rigid enough to ensure swift implementation. An active use of efficient project organizations enabling relevant resources to be directed towards the change process. Formalizing the champion role within the organization ensuring an efficient day-to-day follow-up of the change process. Close collaboration with relevant actors in the company's surroundings, most notably major customers.
The ability to focus on these factors enabled the building of an overall "capacity for innovation" within the company, meaning an ability to continuously harvest, develop, and implement new and transformative tools and work processes in the daily operations.
The lessons uncovered in this study are highly relevant for other companies looking to prepare themselves for the increasingly changing demands the industry is facing. Operating with an organizational setup able to continuously change and innovate can prove decisive in the years to come.
Enabling Agile and Responsive Workflow Automation: A Hydraulic Fracture Design Case Study
Authors: Strobel Marshal , Carvajal Gustavo , Szatny Michael , Peries Chaminda 
Published: March 2012

Abstract
Hydraulic fracture design is an example of what is largely a manual process that requires interaction with a number of different software applications to obtain fracture geometry, production constraints, production sensitivity criteria, and NPV scenarios. When the goal is an optimized fracture design, the process is especially onerous, as it requires iterative interactions with reservoir simulators, nodal programs, economics models, drilling-well design systems, and stimulation design tools to arrive at a suitable design.
Previous papers have detailed the benefits that can be derived from the automation of operations, engineering workflows, and production workflows in general. A major service company was able to quickly provide workflow automation benefits to an East Texas field with the aid of its workflow automation software. In the East Texas field, the service company was able to preserve the provided business service, yet change many of the connections with other software applications that were used to deliver the business benefit, as well as the engineering methods used to optimize the design.
The GoM Lower Tertiary Wilcox Sand Field was also deemed a good candidate by a major service company to operational and production workflow automation, given its low PI, high-cost wells, HPHT tech challenges, and production uncertainty. This fracture workflow uses a unique holistic combination of tools, which are coupled in a way as to reflect the actual economic values of various fracture scenarios.
With the Microsoft Upstream Reference Architecture (MURA) initiative, Microsoft, along with several of its E&P partners, prescribes this approach, which focuses on achieving a level of interoperability between software solutions used by the industry.
Self-Help and Leveraging Scale via the Wells Advanced Collaborative Environment's Global Community of Practice
Authors: Sawaryn S. J. , Deady A. , Lennox S. , Moore-Cernoch K. , Morrison J. M. , Saunders M. 
Published: March 2012

Abstract
The well's Advanced Collaborative Environment (ACE) Community of Practice (CoP) was formed in March 2009 at BP's senior management request, to share good practice and promote standardisation in this area. Its mandate was one of self help and leveraging scale, but working through influence and consensus, with management support rather than by direct authority. It was also required to adhere to company IT standards and technology strategy.
At the time of the CoP's formation, collaborative environments had been commissioned in various company locations worldwide, including Aberdeen, Baku, Houston, Stavanger and Tangguh. In the absence of any unifying well's concept, each of these centres had been developed independently, strongly influenced by local ideas, needs and resources. The approach was typical of the innovation stage referred to in the conference programme, but it was evident that connectivity between the different locations and with other disciplines was lacking and that effort was duplicated.
Today the CoP has over 30 members, spanning wells, subsurface, IT and wells technology from 12 locations worldwide. It meets virtually, involving the widest possible membership in the different time zones. It has been instrumental in progressing and communicating standards, supporting the introduction and use of common tools and technology, leveraging its knowledge and expertise and helping start-ups in new areas. Overall the CoP has been a great success. The paper describes the CoP's evolution, from its formation to the present day and critically examines its achievements, shortfalls and future goals.
In a rapidly changing technical environment, achieving and maintaining alignment between the diverse stakeholders in a medium to large organisation can be challenging. The CoP has earned its credibility and has proved to be an effective means of sharing experience and making good use of scarce resources, both keys for adoption at scale.
Field of the Future is a registered trademark of BP.
SAGD Field Trial for a New Intelligent-Well Completions Strategy to Increase Thermal EOR Recoveries
Authors: Shaw Joel , Bedry Mark 
Published: March 2012

Abstract
Well segmentation and instrumentation have been used to improve steam injection and production conformance in a completions strategy for a thermal-enhanced oil recovery (EOR) project by using intelligent well technology and interval control valves (ICVs). The initial field trial is ongoing in the injector of a Northern Alberta steam-assisted gravity drainage (SAGD) well pair. The development of the completion technology suitable for thermal conditions, initial field trial results and the plans for further development are described in this paper. The application modeling shows that, depending on the level of heterogeneity present in the reservoir, a 45% reduction in the steam-oil ratio and an almost 70% increase in recovery can be achieved in a SAGD process when both improved injection conformance and producer differential steam-trap control can be applied in a segmented horizontal well pair. A cost-effective, intelligent-well completion solution to achieve this segmentation and control has the potential to add substantial value to field developments through improved steam conformance. This will result in increased energy efficiency and oil recovery. The method under development is also applicable to a wide range of other thermal EOR processes such as cyclic steam stimulation (CSS), steam drive, and variations, including, for example, those involving solvent additives.
The initial field deployment in the injector well was initiated to prove the technology, to demonstrate the feasibility of modifying the steam distribution, and to obtain best practices for future developments. A successful installation and commissioning of the intelligent completion has validated the technology. Lessons learned are highlighted. Early injection test results and data show a significant increase in the understanding of the injection and production behavior in the well pair. A test program to optimize the distribution of the steam injection in the well is underway, and the results are discussed. The intelligent completion technology under trial and proposed further developments should enable more extensive use of downhole measurement and control in thermal EOR projects than has been possible to date.
Retrieval and Reinstallation of a Large-Diameter Single-Trip Straddle System
Authors: Tomich M. , Bramwell J. 
Published: March 2012

Abstract
Early in 2008, a newly designed 7" single trip retrievable straddle packer system, with 25ft between packing elements, was installed in a water injection well in Eastern Algeria. The objective of the operation was to isolate a thief zone which was taking the majority of the injected water and then cross-flowing to other zones when the well was shut in. The installation was successful and subsequent logs indicated that the straddle was still holding in 2011 and thus continuing to prevent injection to the thief zone.
The installation and subsequent performance of the straddle were considered satisfactory but in order to further evaluate the system with a view to using more such tools in future operations, it was decided to perform a retrieval, inspection, redress and re-installation of the straddle in the same well to evaluate the ease with which this could be done. Though the straddle was run using electric line, the forces required to unset and retrieve it were such that the use of coiled tubing (CT) was necessary. Due to the length limitations imposed by the CT injection system, and the overall length of the pulling tool and straddle, a method was devised to use a combination of electric wireline and CT to perform the retrieval process. This would require deployment of the pulling tool by electric line using a deployment bar to hang it off in the BOPs and subsequent re-attachment to the CT before running in the well - this method would be reversed when pulling out of the hole after retrieval. Subsequent re-installation could however be performed using electric line as in the initial installation.
In this paper the authors will review the situation and the unique retrieval techniques that were used, describe in detail the successful operation to retrieve, redress and re-install the straddle and discuss the results of the inspection of the tool and the redress requirements after 3 years in service.
Rib-Steered Motor Technology: The Revolutionary Approach Extends the Coiled Tubing Drilling Application Scope
Authors: Ross Matthew , Anyanwu Okechukwu N. , Klotz Christian , Ulrich Carl D. 
Published: March 2012

Abstract
Traditional coiled tubing drilling (CTD) operations employ bent mud motors to create bit rotation that enable diverging wellpaths. As coil rotation is not applicable, an additional downhole orientation device is required for directional control of the motor. For more than a decade, this setup has enabled reliable and successful CTD operations worldwide. It also has been, over time, driven to its limits. Several apparent drawbacks with this platform include unfavorable drag that limits the maximum horizontal reach, suboptimal wellbore quality causing challenges in subsequent liner running operations or the increased distance of inclination measurements from the drilling bit. While some of those can be managed to a certain extent, others are intrinsic to the bent-motor steering concept. The need to further improving well construction economics requires that the CTD operational envelope be extended with new concepts and technologies.
This paper covers the introduction and utilization of a new directional steering technology that is based on the concept of closed-loop steerable drilling systems from rotary drilling applications. The new 3-in. rib-steered motor (RSM) design includes three hydraulically expandable ribs that are controlled from surface during drilling. In such setup required wellbore contact forces are generated that are necessary for drilling complex 3D well profiles. The RSM platform also offers the capability to drill tangents, which is impossible with the combination of bent motors and downhole orientation devices. Testing of this new platform commenced in 2008 in Alaska for BP, and it was further improved to become a new standard technology for horizontal or tangent sections in high-end CTD applications. Since then, 3-in. RSM bottomhole assemblies have drilled more than 23,000 feet in more than 13 wells in Alaska. Compared to bent motor drilling, RSM technology improves weight transfer and enables precise control of weight on bit to total depth (TD) for significant extension in lateral section length. It also improves hole quality to make liner running operations more reliable, and reduces non-drilling time by reducing the amount of required wiper trips for hole cleaning purposes. This paper discusses these aspects in more detail and uses available field data to show and support the technology’s benefits and its impacts on project economics.
Successful Coiled-Tubing Conveyed Water-Shutoff Treatments in Gas Reservoirs in Indonesia
Authors: Samvelova M. , Noguera J. , Kusuma D. H. , Mahardhini A. 
Published: March 2012

Abstract
The majority of the reservoirs in a study field in Indonesia are gas producers with water. The average production is more than 650 MMscf/D with 11,000 BWPD. The reservoirs are characterized as multilayered sandstone water-sensitive formations with permeability ranging from 0.1 md to 2 darcy. The measured depths (MD) of the perforated producing zones extend from 9,400 to 11,100 ft, with an average reservoir bottomhole temperature of 240°F (115°C).
The study field has experienced significant water breakthrough in recent years, which has led to adrastic reduction in the total gas production per well. To increase gas production, it is required toreduce the water-gas ratio (WGR) to prevent the water-source reservoirs from killing the other producing layers and to stabilize the well’s flowing conditions. This could be achieved by shutting off the undesired water production. The main challenge of the study field is the number of reservoirsopened per well (&gt;30 perforated reservoirs), with short distances between the perforated zones. Mechanical isolation was impossible in these cases because it would create restrictions during future interventions.
A multidisciplinary group developed an innovative solution to shut off the water in these wells. The solution included a straddle system that consist of an inflatable retrievable bridge plug used as bottom isolation and an inflatable packer conveyed with coiled tubing (CT) as upper isolation, combined with a chemical water-shutoff treatment. The system was successful in shutting off the watered-outsands while keeping the upper reservoirs producing to date. This CT placement technique opened many opportunities for selective water-shutoff treatments of middle zones. This paper discusses the methodology of the job design, with a detailed operation sequence and results obtained from the field, including production results of some of the treatments pumped in the study field.
An Improved Method of Manipulating and Evaluating Sliding Sleeves
Authors: Kenison M. , Adil A. R. , Morrison R. , Valencia C. F. , Powell B. , Hermelink H. , Frederiksen C. H. 
Published: March 2012

Abstract
Sliding sleeves are used to enable selective zonal isolation and can improve water and gas management throughout the life of the well. Because of the large shifting force and extended reach required to operate sliding sleeves in long horizontals, coiled tubing is typically used. Coiled tubing also provides the benefit of pumping fluids to clean out or treat the well. A surface load measurement withcoiled tubing may sometimes provide a positive indication of shifting, but not in all cases. Also, surface measurements alone do not provide a way to determine the sleeve position. This paper describes conventional techniques used to confirm proper shifting and determine sleeve position. An improved method is presented, along with yard and field test results.