bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pressure Gradient Testing with a New Formation Pressure Testing During Drilling Tool
Authors: Meister Matthias , Pragt Jos , Buysch Arno , Witte Johannes , Due Gisle Nordahl , Hope Randi 
Published: December 2007

Abstract
Formation pore pressure is a key parameter for reservoir management in the Troll field. The pressure measurement traditionally performed on wireline is time consuming, especially in deviated wells. To provide the service earlier and more efficiently, a formation pressure tester has been developed as part of a Logging While Drilling bottom hole assembly. The tool measures pore pressures during brief pauses of the drilling process by extending a pad to the borehole wall, forming a seal against the formation, and performing a series of drawdowns.
To meet the challenges of short station duration and limited telemetry rates, the new tool is equipped with a downhole intelligent system for real-time operational decision. The flexibility of the design of the new tool allows basic pressure tests with preset draw down and buildup tests with preset fixed volume and rate, or repeated draw down and buildup tests with different drawdown rates and volumes optimized downhole in real-time.
The new LWD formation pressure testing tool (TesTrak) has been successfully applied in three deviated wells with inclinations between 50 and 90 degrees in the Troll field. In eight bit runs and 235 rotational hours, 231 pressure points at 89 stations have been performed over a drilling distance of 10,780 ft. Post-well analyses of the pressure data have further added confidence to the real-time data acquired during drilling. The objective in the first field test was to establish the pressure in a high and a low mobility sandstone section on both sides of an intersecting fault zone. In addition, reservoir connectivity between two compartments was proven with the real-time data. The objective of the second field test was to establish a fluid gradient in the well during a small TVD change in the horizontal section. The tool provided a real-time fluid gradient in the reservoir section over a 20 feet TVD drop over a 1000 ft long section. The pressure data were also used to optimize the mud program and drill the well efficiently. In the third field test three pressure gradients (one gas, and two water gradients) were established, which helped to determine reservoir depletion characteristics.
The tool performed well and subsequent analysis of memory data supported the real-time pressure measurements. The data obtained fit perfectly to the pre-drill model, which was based on wireline formation tester measurements in off- set wells. The successful operation of the LWD Formation Pressure Tester demonstrates a good potential for time/cost savings by replacing separate wireline- or pipe-conveyed formation pressure logging jobs. The pressure data could also be applied for optimizing the mud program and hence improve drilling efficiency.
Software Simulation and System Design of Dynamic Killing Technique
Authors: Blotto Paola , Tambini Mauro , Dellarole Edoardo , Bonuccelli Michele 
Published: December 2007

Abstract
Uncontrolled eruption of a well is one of the most critical accidents that can occur in the exploration and exploitation of hydrocarbon fields. Several well control methods have been developed to bring blowout wells under control as quickly as possible.
The dynamic killing technique is typically adopted when a relief well needs to control the event. The method calls for bringing the blowout well under control by pumping water (or brine) at a flowrate sufficient to exceed the formation pressure of the blowing well. This phenomenon occurs through a combination of kill fluid static head and frictional pressure losses of kill fluid in the blowout well.
Dynamic killing is constituted by a complex multi-phase fluid dynamic system with a complex geometry: blowing well, relief well and reservoir. An advanced model able to simulate the killing phenomenon during all its transients is necessary for applicability screening and system design.
A software has been developed under an HSE R&D project and implemented by an integrated work team made up of the safety, production, drilling and reservoir engineering departments of oil and service companies.
The dynamic killing software, by simulating the killing transient with a series of loops through submodels, correlates killing flowrate, breakthrough and killing time, relief bottom hole pressure and required killing pump head and power as outputs.
This model is able to simulate the dynamic killing of an atmospheric or underwater blowout event. It is also able to analyze the in-string killing disabling the reservoir submodel. This paper fully describes the dynamic killing model in terms of both subroutines (blowing well, relief well and reservoir models) and software applications (method applicability, system design, main killing parameters).
In addition, the results of software validation simulating dynamic killing cases in the field are reported. This analysis indicates good accuracy of the model in terms of transient duration and killing requirements.
Installation of the World's First All-Electric Intelligent Completion System in a Deepwater Well
Authors: Moreira Oswaldo M. 
Published: December 2007

Abstract
The world's first all-electric intelligent completion installation in a subsea deepwater well, carried out in August 2003, represented the culmination of five years of joint development, testing and onshore field trials by the operator, Petróleo Brasileiro S/A (Petrobras) and completion contractor, Baker Oil Tools. It also illustrates the extent to which new oilfield technologies, particularly those related to subsea/deepwater applications, have historically met with resistance for wide acceptance.
This paper describes the various phases of the five-year project by Petrobras and Baker Oil Tools to qualify the all-electric intelligent well system for deepwater applications. The paper also highlights lessons learned at each phase of the development project and describes how those lessons were applied in ensuing phases to improve the design and functionality of the intelligent completion system. Finally, the paper offers an explanation as to why acceptance for this type of system has been restrained as well as a prognosis for future system development and acceptance.
Aligning KM with Business Needs
Authors: Diz Agustín , Felder Benjamín , Girela Immaculada , Paredes Sergio 
Published: December 2007

Abstract
At Repsol a KM program is being implemented which considers 4 fundamentalaspects: a. Communities of Practice. b. Links to Training (what we know andwhat we don't know). c. Recognition. d. Quality Metrics.
In E&P, over 10 communities are in place, and working. These communitieshave enabled new ideas and processes for areas that go from training, businessprocesses, all the way to alignment with Business Strategy.
The issues we have tackled, problems encountered, and specific results willbe presented and discussed. Critical aspects, such as pitfalls encountered andfailures will be addressed as key learnings to be shared.
One example has been the increase in supply of workshops and courses(including mixtures of e-Learning with classroom work) for employees to attend, which needs to be properly controlled. Another is the work integrating specificbusiness processes with information systems for better decision making, whichcommunities have enabled simply by being able to draw on all the appropriatepersons from different Business Units.
Flow Profiling via Distributed Temperature Sensor (DTS) System - Expectation and Reality
Authors: Ouyang Liang-Biao , Belanger Dave 
Published: December 2007

Abstract
Permanent downhole monitoring can provide valuable information for production decisions in real time without the need to perform an intervention to collect data. One of the commercial permanent monitoring technologies is fiber-optic distributed temperature sensor (DTS) which can record the wellbore temperature profile in real time with decent accuracy and resolution. A key potential application for DTS data is to profile injection or production for wells, which is the primary motivation and focus for this project.
In the present paper a thermal model recently developed for single phase and multiphase fluid flow along a vertical, deviated or horizontal well will first be briefly described. The model can be applied for both wellbore temperature prediction (&lt;i&gt;forward modeling&lt;/i&gt;) and flow profiling using a measured temperature profile (&lt;i&gt;inverse problem&lt;/i&gt;).
The model has successfully been applied for investigating key thermal characteristics of single phase and multiphase fluid flow along a wellbore. In particular, the dependence of wellbore temperature upon phases, flow profile, fluid type, fluid properties, well deviation, and Joule-Thomson effect, will be demonstrated in the paper. The model has further been adapted for directly predicting production and injection profiles (i.e., flow profiling) based on given wellbore temperature profile. The potential impact of noise in the DTS measurement on flow profiling has been explored.
It is found that the wellbore temperature does not change significantly along horizontal or near horizontal sections due to the small variation in geothermal temperature, therefore, just based on DTS data, the amount and the location of each fluid entry would be difficult to be identified. The current study shows that a maximum wellbore deviation of 75 degrees should be honored to appropriately estimate flow profile directly through DTS data. The study has also led to an observation that under certain circumstances like multiphase flow, a production profile may be determined via DTS temperature measurement with extra data or information provided. The types of the extra measurements and the appropriate approaches will be recommended.
Petroleum Engineering Education - Challenges and Changes for the Next 20 Years
Authors: Cunha J. C. , Cunha Luciane B. 
Published: December 2007

Abstract
This article indicates some basic knowledge and skills that should be present on the education of today&#39;s petroleum engineering students. Concurrently it presents some thoughts and points out directions for petroleum engineering education in the next few decades.
The importance of interaction between petroleum engineering schools and the oil industry is analyzed and some directions to improvement of this relationship are given.
The challenge and importance of attracting better and brightest students are commented and some suggestions related to how schools and industry should jointly participate in the efforts to keenly achieve this goal are listed.
The Importance of Rigorous Asset Analysis as Input to Portfolio Optimization: Practical Lessons from Recent Experience
Authors: Simpson G. S. , Ross J. G. , Ghazi T. Y. 
Published: December 2007

Abstract
There is a growing suite of innovative new portfolio analysis tools available, but there are still many questions about how to turn the theories, tools and techniques into tangible profit improvements. One thing is clear, however. The results of portfolio optimization strongly depend on the quality of the standalone asset analyses that are used as input.
This paper illustrates ways of avoiding pitfalls and improving the rigor of standalone asset analyses. It also sets out methods for understanding, implementing and deriving the best value from the latest project optimization techniques.
Specifically, the paper illustrates the importance of: Understanding the interaction between standalone asset analyses, portfolio optimization and portfolio management strategy formulationApplying a structured framework for analyzing, planning and managing the development of projectsUsing a new synergistic approach to the evaluation of critical assets that compresses decision cycles and enables a large technical-to-business team to discover potential step-changes in project profitability and more rigorously assess uncertaintyFinding a common language between the different functions involved in portfolio management, facilitating communication and constant, dynamic innovation in proceduresBuilding a corporate culture that understands risk and uncertainty, knows how to deal with them, and actively encourages advances in asset analysis and portfolio management practices
The combination of these techniques allows a much closer approximation to the "full, risked, probabilistic values"1 of individual assets that are required as inputs to portfolio optimization analysis. Thus, the full power of portfolio optimization can be realized, through identifying the most profitable combination of projects, making optimal use of resources and thereby driving up a company's profits.
Thunder Horse Drilling Riser Break – The Road to Recovery
Authors: Kirton Bill , Wulf Gary , Henderson Bill 
Published: December 2007

Abstract
This article presents key learnings by BP's Wells Team on the Thunder Horse project after responding to a major incident— the break of the drilling riser on the Discoverer Enterprise drillship in May 2003 in the Gulf of Mexico. Even though BP has established policies for the immediate incident response phase and conducts training exercises, there is less focus on the later recovery phase. This paper increases the awareness of critical project management issues that may arise during transition from the response to recovery phase after a major incident.
Design of Intelligent Well Downhole Valves for Adjustable Flow Control
Authors: Konopczynski Michael , Ajayi Arashi 
Published: December 2007

Abstract
This paper describes the considerations and integrated design process for specifying the Cv characteristics of an adjustable flow control valve for an intelligent well. The paper emphasizes the need to consider the complete well as a control system, including inflow, choke performance and well bore outflow performance.
The paper describes a method for establishing the most suitable flow control design for the application. The method combines nodal analysis and choke performance modelling to model the behaviour of the entire well bore system. This analysis is extended to multiple layer or multiple zone intelligent well completions. An example of the analysis is presented.
Dilution Strategies for Wax Management and Control for Deepwater Development from a Flow Assurance Perspective: Part I – Current Practice and Perspective
Authors: Singh Aditya , Benavides María S. , Saint Marcoux Jean-Francois , Barrufet María A. 
Published: December 2007

Abstract
Oils with high wax content may cause pipeline plugging and deterioration of equipment, resulting in production shutdowns and economic losses. At present, various mechanical, thermal and chemical methods are used for wax management, however these methods can cause additional problems and can be very expensive. Dilution can be used as an alternative or can be combined with current wax-management methods. This paper identifies dilution strategies for a range of waxy crudes from different oil producing regions of the world.
Prevention and control of wax deposits by blending heavy fractions of oil with lighter fractions is achieved with tools currently available in the industry. Mixing rules and blending correlations to suppress the wax appearance temperature (WAT) can be developed. A database of fluids with a range of wax contents from different regions of the world was created and used in this analysis. A way forward in modeling, control, and remediation is proposed, and possible areas of further research and development are identified.
Expensive thermal and chemical solutions are currently required to produce fluids with high wax content in deep-and ultra deep-water field developments.
The results are promising. Unique flow-assurance solutions can be achieved by addition of diluent. Injecting 6 to 23 MSCF Lift gas/1000 bbl crude in low GOR fluids can achieve a WAT reduction of 6 to 7°F. Other diluents evaluated demonstrated that with ratios of 0.5 – 4 bbls of diluent/1000 bbls of crude, a WAT reduction of 6-13°F could be achieved.
Improved Horizontal Well Stimulations in the Bakken Formation, Williston Basin, Montana
Authors: Wiley Charles , Barree Bob , Eberhard Mike , Lantz Tom 
Published: December 2007

Abstract
The Bakken formation in the Williston Basin of Montana has undergone rejuvenation thanks to the success of horizontal drilling and completions. Over the last several years there has been an evolution in the drilling and completion methodology, which has resulted in significant improvements in well productivity. Although the horizontal wells will produce at economic rates without stimulation, hydraulic fracturing increases well productivity significantly. For the program discussed in this paper, the wells are drilled for longitudinal fracture orientation. The original wellbores had cemented liners and employed the limited-entry technique to distribute the fracture treatment. This program now uses noncemented liners and a modified fracture treatment with diverter stages.
This paper presents a review of the approach taken to evaluate the most effective way to complete and hydraulically fracture these laterals. It documents the evolution of the hydraulic fracture design and wellbore configurations. It also presents results showing the improvements in proppant distribution along the wellbore caused by changes in fracture treatment design and its impact on well productivity.
Downhole Impulse vs.Downhole Impacts Improve Recovery of Stuck Retrievable Packers
Authors: Haughton David B. , DeGeare Joe P. 
Published: December 2007

Abstract
Stuck retrievable packers are most often fished out of the hole with a jarring string. Essentially, this is a hammer that is used to beat the packer out. The jarring operation proceeds until either the jars quit or the mandrel is jarred out of the packer. In either case, a milling assembly must be run, which can take more than one trip to complete. Experience has shown that recovery of stuck packers by conventional means is very difficult and time consuming. On some deepwater floating rigs with day rates from $200,000 to $500,000, a stuck packer that takes days to recover can have a catastrophic cost.
Recent downhole vibration and impulse studies have shown that downhole impulses could be considerably more effective than jarring in retrieving packers and other point-stuck equipment. By imparting - impulses downhole to the stuck object, there is no need for a high-strength work string. The chances of pulling the mandrel out of the packer or sticking the packer tighter in the wellbore are greatly reduced.
Impulses work independently from overpull, so it is ideal for horizontal or high-angle wellbores. Another advantage is that the work string does not have to be reciprocated as much as with a jarring string. When pulling out of a wellbore, a packer can get hung up on restrictions such as casing collars. Jarring strings cannot be reset unless the packer can be set down, which allows the jars to close and reset. A downhole impulse tool works only on fluid pumped through the tool, so it can be activated at any time by rigging up a pump line. There is no need to set down the string. This new method has been shown to be an effective alternative to conventional jarring tools. Cost savings can be substantial.
This paper focuses on the development, operation, and applications of this technology. Case histories are examined in detail showing advantages over conventional means.
A Fresh Look At Stimulating Unconsolidated Sands With Proppant-Laden Fluids
Authors: Di Lullo Gino , Curtis James , Gomez Julio 
Published: December 2007

Abstract
Can unconsolidated sands, with no intergranular cohesion forces, really be hydraulically fractured? Does conventional hydraulic fracturing theory adequately explain treatment behavior and production results? If the unconsolidated formation is considered to be a fluidized sand bed, is the classical linear-elastic two-wing hydraulic frac assumption still valid? Alternative proppant stimulation mechanisms may better describe the process, including squeezing or forcing by viscous fingering of the high-permeability proppant slurry into the formation. In this scenario, traditional fracturing design parameters such as pad volume, pump rate, proppant concentration and especially fluid viscosity will have new and significantly different effects on the treatment outcome.
This paper explores these concepts and shows how they can explain both treating behavior and production responses of so-called "frac jobs" or "sand-oil-squeezes". Alternative treatment and fluid design criteria are proposed to achieve more consistent and predictable production responses, based on field performance.
Changing Safety Paradigms in the Oil and Gas Industry
Authors: Ratliff Matt 
Published: December 2007

Abstract
The oil and gas industry boasts a hard-earned reputation of being able to get the job done anytime, anywhere. Unfortunately, this distinction has also produced an inherent attitude that too often puts the job first, regardless of personal safety. To confront the ongoing stigma of poor safety practices, the industry began promoting a "safety first" approach. As admirable as this goal is, many health, safety, and environmental (HSE) professionals found that deeply ingrained attitudes and practices are difficult to change. HSE personnel often fail to convey their message effectively because they lack not just a formal program but also a willing audience.
Talking "safety first" is merely the first step to promoting a successful HSE culture within the industry. The next key step requires the development of an HSE management system that allows all HSE professionals to promote a consistent message to the industry. Proven success stories provide models to replicate and encouragement for the industry to change.
This paper will discuss some of the practices currently engrained in the industry and outline methods to help shift current HSE patterns to consider safety first. Leadership practices that supervisors can implement to define and shape employee behavior will also be detailed. To conclude, this paper will discuss the characteristics of a program that produced a successful HSE culture and convey steps others can take to modify the existing industry paradigm.
New Technologies Combine to Reduce Drilling Costs in Ultradeepwater Applications
Authors: Touboul Nicolas , Womble Lee , Kotrla John , Keith Neal 
Published: December 2007

Abstract
As the oil and gas industry matures, so does its technology and equipment. As a drilling rig gets older, it becomes increasingly challenging to use it to explore for untapped deep reserves. Offshore rig builders are constantly manufacturing rigs with new, sophisticated capabilities, thereby widening the technology gap between the new rigs and the aging ones. As a result, many operators of older rigs are modifying their rigs to compete with newer ones.
Using a modified second-generation semi-submersible rig in Indonesia, Total was able to reach target depth in an ultra-deepwater well by deploying a combination of surface stack drilling technology, a subsea shut-off device known as an environmental safe guard (ESG), and solid expandable tubular technology. If conventional casing had been used, the optimal hole size at total depth (TD) would have been impossible to attain and economically unfeasible without the use of a fourth or fifth generation semi-submersible or drillship.
This paper describes the safe and successful integration of new technologies that enable surface stack drilling with modified second- or third-generation semi-submersible rigs in environmentally less-benign areas, including the Gulf of Mexico. In addition, the paper will discuss the deployment of solid expandable tubular technology from a modified second-generation rig and show how this technology enabled the operator to achieve a sufficient hole size at total depth while maintaining an economically viable operation.