bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Universal Formulation for the Prediction of Capillary Pressure
Authors: Goda Hussam (Sam) , Behrenbruch Peter 
Published: October 2011

Abstract
Capillary pressure and associated relative permeability are special core analysis parameters which are vital in accurately describing fluid distributions and movement in porous media when two (or more) immiscible fluids are present. Conventionally, the determination of capillary pressure requires laboratory experiments, which are expensive and time consuming. Assuming that core material is available, typically a limited number of core plugs are considered for testing, often resulting in incomplete reservoir description. This situation then leads to motivation for developing mathematical capillary pressure models, as an alternative to adequately describing fluid behaviour in reservoirs.
The well known Carman-Kozeny (C-K) equation (Carman 1937; Kozeny 1927) is commonly used to model permeability as a function of other pore structure parameters. More recently parametric groups were established for the C-K equation, which are in regular use in reservoir characterisation. Specifically, the determination of flow zone units for the description of distinct (litho)facies is now widely used in linking fluid flow to geological descriptions. In this paper, a new and innovative deployment of the C-K equation is investigated to derive capillary pressure relationships.
The new mechanistic, drainage capillary pressure model uses the principle of "effective saturation", and is developed and validated with data sets from onshore and offshore Australian hydrocarbon basins, giving a good comparison with laboratory measurements and other established models. Most significantly, the new mechanistic formulation does not just fit capillary relationships but is able to predict drainage curves by knowing or assuming up to six properties: absolute permeability; effective porosity; irreducible water saturation; maximum capillary pressure, which may be related to a particular reservoir situation or laboratory standard; capillary entry pressure; and associated entry water saturation. The last two parameters are typically required for a higher permeability (or better quality) rock. Absolute permeability is incorporated indirectly. Furthermore, there is no requirement for correlation parameters or constants but the analysis determines two parameters which give a measure of heterogeneity of the sample being investigated.
A Novel Well Annular Barrier Solution Alternative to Swellable Casing Packers
Authors: Plessing Hans , Arnskov Michael Macdonald 
Published: October 2011

Abstract
Having safe effective annular barriers that can be used for annular isolation is the key for managing wells. This has traditionally been done by either cementing the annulus or through the use of swellable packers.
The use of cement as annular isolation usually is considered as the industry standard, however it is a complicated, time-consuming and expensive to deploy. Alternatives, such as polymer-based swellable packers, are usually less complicated to deploy, but the degradable polymers invoke a risk in the typically harsh environment of a well.
The approach presented is based on a solid metal expandable system developed for the applications where swellable external casing packers traditionally have been used. The well annular barrier provides long term robust and reliable zonal isolation in cemented or un-cemented wellbores and may be used in conjunction with casing as well as liners. It also provides higher differential pressure capacity and higher expansion ratio to running OD without compromising the inner diameter. Consequently it does not impair or restrict flow conditions and furthermore enables subsequent well maintenance to take place unhindered.
The paper presents the results of the development and testing of the new solid metal expandable system for external casing applications and discuss the rationality behind the technology as well as the experience gained.
Production Tubing Frac Pack: An Unconventional Multi-Zone Design with Significant Cost Savings
Authors: Patterson Richard , Ross Colby , Larpenter Mike 
Published: October 2011

Abstract
The conventional process of frac packing that was initiated in the early 1990s and revolutionized the industry is well documented in the literature (Meese, et. al., 1994, and Mullen, et. al., 1994). Frac packing provided sand control as well as stimulation in unconsolidated reservoirs, and it has played a key role in enhancing productivity and adding reserves to many wells. The results of frac packing in unconsolidated reservoirs have been so positive, and its acceptance so widespread, that today it is considered standard practice though operators have customized numerous variations of frac packing for specific types of applications. For all the completion processes for frac packing that have been developed to date, one common factor is that rig assist is usually required throughout the entire process, including the phase of fracing the well. Additionally, multizone stack packing completion systems have evolved so that it is common practice to stack completions to economize the high cost of rig service that is involved with intervention (Brannon, et. al, 1991, and Bennett, et. al, 1996).
This paper describes an innovative and more economical multi-zone frac packing design known as production tubing frac packing (PTFP), which was developed in 2009 in the Gulf of Mexico. The new design combines the steps of perforating, completion setting, and frac packing into a single trip. PTFP is in the initial phase of a learning curve but has already proven to be more economical and potentially to have a similar impact on the industry as both frac packing and stack packing zones. With PTFP, much of the completion phase is performed through the production tubing after the rig assist has been demobilized, with the biggest savings realized during the rigless frac phase. This paper will cover all phases of the PTFP completion technique and will discuss three case histories.
Application of Single Well Chemical Tracer Tests to Determine Remaining Oil Saturation in Deepwater Turbidite Reservoirs
Authors: DeZabala E. , Parekh B. , Solis H. , Choudhary M. , Armentrout L. , Carlisle C. 
Published: October 2011

Abstract
Remaining oil saturation (ROS) and waterflood residual oil saturation (Sorw) are key parameters for reservoir modeling and waterflood management in a group of heterogeneous deepwater turbidite reservoirs. A large amount of laboratory special core analysis (SCAL) data indicated high Sorw values and a large target potential target for chemical EOR (enhanced oil recovery). Available SCAL data was not considered reliable. Acquiring additional core was considered to be too costly and too risky due to the highly deviated well paths required for new wells. Single Well Chemical Tracer Tests (SWCTT's) in producing wells were the only viable alternative. This paper describes – to our knowledge – the first applications of SWCTT in a deepwater setting.
An early 2010 SWCTT showed ROS / Sorw to be much lower than expected but test interpretation was uncertain. The 1st SWCTT provided a valuable learning experience to improve test design and execution and to improve on significant logistical challenges in the deepwater setting. Using lessons learned we performed two additional SWCTT's in late 2010. The later SWCTT's included well integrity pre-tests and smaller completion intervals. Typical SWCTT volumes were ~5,000 bbl of seawater containing tracers with a depth of investigation of ~4 to 5 meters.
All three SWCTT's indicated low Sorw values, ranging from 0.05 to 0.20 with a nominal average of 0.15. Similar results from all three SWCTT's indicate that microscopic displacement efficiency is very good; eliminating the option of chemical EOR. The current field development plan is focused on improving volumetric sweep efficiency.
Properly designed and executed SWCTT's can be considered as large-scale "laboratory waterflood tests" at true reservoir conditions (e.g., live oil, wettability and stress history). Compared to conventional SCAL tests using small plug samples, SWCTT's see a much larger rock volume and avoid wettability alteration issues that plague modern cores taken with OBM (oil based mud). Though logistically challenging in deepwater, SWCTT's can be more cost- and time-effective than taking a new core.
The Practice and Evolution of Torque and Drag Reduction: Theory and Field Results
Authors: McCormick John E. , Chiu TzuFang 
Published: October 2011

Abstract
With the global trend moving toward drilling deep water wells, ultra-extended reach wells (u-ERW) and complex geometry wells, we can no longer ignore the drilling limitations caused by high torque and drag forces. Extreme torque and drag, especially unplanned, can be detrimental to drilling operations. Over the years, engineers have developed numerous ways to challenge the drilling limitations by reducing torque and drag forces in order to drill further and deeper. This paper attempts to describe the practices and the evolution of torque and drag reduction methods. The different torque and drag reduction methods that this paper focuses on are listed below.
Wellpath design Light weight string components Lubricants Hole cleaning Co-polymer beads Mechanical friction reduction tools Increased drill string and rig capability
In highly inclined wells, solutions to problematic torque and drag are essential in order to complete the drilling and completion operations. Because many restrictions are imposed by the drilling rig, top drive, wellpath and drilling components, engineers have came up with ways to reduce torque and drag while drilling. There are weight limitations that a rig can provide, especially in non-rotating operations such as slide drilling. If the compressive forces in the drill string are too high, bucking will occur. In an extended reach well (ERW), two common problems with torque are the friction resistance to drill string rotation and the make-up torque limitations. If the rotary torque is too high, torsional failure would result. Therefore, it is essential for engineers to accurately account for the torque and drag forces and attempt to reduce them in order to prohibit these scenarios from occurring. At the same time, it is the engineer's responsibility to ensure that we do not over-design to accommodate unnecessary needs.
Plastering Effect of Casing Drilling; A Qualitative Analysis of Pipe Size Contribution
Authors: Karimi Moji , Moellendick Eric , Holt Calvin 
Published: October 2011

Abstract
Casing Drilling is a process in which the well is drilled and cased simultaneously. The original purpose of developing this technology was to eliminate the Non-Productive Time (NPT) associated with tripping out drill pipe and running casing. However, during the early implementation of the technology other benefits were observed while drilling with the casing. In this study the authors explain how these benefits can be related to the larger diameter of the casing compared to drill pipe.
The Plastering Effect is an inherent and unique feature of Casing Drilling that strengthens the wellbore, prevents lost circulation, and mitigates formation damage. Plastering Effect augments the pressure containment of the wellbore by smearing the drilling cuttings and available PSD (Particle Size Distribution) into the formation face, hence sealing the pore spaces. This continuous process creates a low porosity, low permeability filter cake on the wellbore wall reducing or preventing losses to the formation and effectively widening the operating mud weight window.
In Casing Drilling operations the casing is used to drill the well so the (pipe size/hole size) ratio will be larger than the ratio when conventional drilling pipe is being used. This feature is a significant contributor creating the Plastering Effect. Casing dynamics is qualitatively compared to drill pipe. Pipe ontact angle and area, side force and momentum, and grinding effect, are analyzed to help understand how the benefits of the Plastering Effect are created and answer the question of why it happens in Casing Drilling and not in conventional drilling.
Casing Drilling has been used successfully in numerous difficult wells to drill through troublesome well sections which would not have been possible to drill with conventional drill pipe techniques. The Plastering Effect of Casing Drilling has been recognized as an enabling tool to overcome difficult drilling challenges. Therefore, understanding its mechanism is crucial to its successful application.
Numerical Modeling of Massive Sand Production
Authors: Wang Jianlin , Yale David , Dasari Ganesh 
Published: October 2011

Abstract
Primary production of heavy oils where significant sand is produced (generally referred to CHOPS for Cold Heavy Oil Production with Sand) is one of the heavy oil recovery processes that have been used to recover bitumen from weakly consolidated reservoirs. There has been significant debate over the exact mechanisms that allow the sand to be produced and whether the process creates a radial zone of high permeability around the wellbore or more linear high permeability channels (wormholes) out from the reservoir. Numerical modeling of the sand production process presents significant numerical challenges mainly because it is a highly-coupled nonlinear process and requires constitutive models that are able to capture the material instability. In this paper, we present a numerical approach to explicitly model the sand production process using the Finite Element Method with Arbitrary Lagrangian Eulerian (ALE) formulation. A number of novel features have been developed and integrated into the ALE formulation to tackle the challenges associated with sand production simulation, such as Eulerian boundary, automatic adaptive remeshing, and advanced constitutive models. By combining these features, our model enables stable coupling between fluid flow and geomechanics, and is capable of modeling large deformation and highly nonlinear geomechanical behaviors. Some examples are provided to demonstrate the soundness, accuracy, and effectiveness of the numerical model. For simulation of the CHOPS process, the model shows that a key aspect of the process is the shifting of overburden stress from parts of the reservoir sand that fail and are produced to those where the sand has not failed. It is this mechanism that allows wormholes to form in the numerical models. The models have also shown conditions which can be induced in the reservoir to enhance formation of wormholes.
Toward Rapid, Expert-Driven Learning Content Development, Embedded Learning And Reduced Time To Market
Authors: Rousseau Meta 
Published: October 2011

Abstract
As the oilfield approaches the long-awaited Big Crew Change and numbers of Generations X and Y employees continue to grow, organizational learning is beginning to reflect this change. Today's new hires tend to have high levels of computer literacy and actively using mobile technology, cloud computing, geo-coded data such as Google Earth, personalized web sites such as Facebook and Linked-In, semantic-aware applications, smart objects and web 2.0 technologies. Naturally, this workforce readily embraces the use of cutting-edge technologies in the work environment as well as for communication and learning.
High levels of comfort with cutting-edge computer and network technologies enable us to develop and implement a greater variety of effective learning solutions. The use of Learning Management Systems (LMS) has become quite common-place and a growing number of early adopters are now implementing Learning Content Development Systems (LCMS) to ensure the effective development and management of rapidly expanding learning libraries.
Through use of the above-mentioned cutting-edge technologies and compatible technical standards as well as the rapidly growing number of user-friendly authoring tools, organizations are able to develop and deliver quality, effective learning solutions. Moreover, the use of web conferencing tools and information mapping environments enable project teams to work well across geographical and time boundaries.
The role of the instructional designer is changing. Facing high demand and close deadlines, instructional designers are spending less time developing learning materials and more on guiding and supporting teams of subject-matter experts through the instructional design process. Instead of working on one or two projects, the typical instructional designer manages several project teams. Through these expert-driven learning solutions, organizations are able to move a significant portion of organizational learning back into the field - and as learning becomes increasingly embedded, organizations are able to cut back on time away from the job and reduce time to market.
An Integrated Approach to Design Completions for Horizontal Wells for Unconventional Reservoirs
Authors: Jain R. , Syal S. , Long T. , Wattenbarger C. , Kosik I. 
Published: October 2011

Abstract
This paper presents a comprehensive and integrated workflow to design completions for a heavy oil recovery process that involves injection and production through the same well. Unlike in traditional completion design, the transient effects are particularly important to consider while analyzing the long-term performance for these types of completions to capture the effect of variations or uncertainties in reservoir and fluid flow characteristics over time. The proposed integrated workflow involves initial screening and selection of flow restricting completions that can meet the desired injection and production performance based on a detailed wellbore hydraulics modeling tool. A select few completions are then analyzed for longer term performance using a reservoir simulator that couples the flow restricting nature of completions with flow in the reservoir. The use of best-in-art wellbore hydraulics model and reservoir simulator in a staged process yields an effective way to assess and optimize the completion design for these wells in a reduced time span. The workflow disclosed here can be used to design effective completions for a broad class of cyclic liquid injection methods for heavy oil resources.
Managing Pressure Drilling with Continous Circulation, A Summary of Eni Experience
Authors: Calderoni A. , Masi S. , Repetto C. , Tufo M. , Molaschi C. , Poloni R. 
Published: October 2011

Abstract
Drilling exploration wells may be challenging due to uncertainties related to several factors like well downhole pressure, pore and fracture pressures, etc. As a result, a well may fail to reach its target depth.
Managed Pressure Drilling (MPD) is a useful technique in challenging conditions. It allows pore and fracture pressures to be accurately calculated while drilling, and the mud weight adjusted accordingly. Besides, it reduces the chance of human errors as it is an automatic device managed by specific software.
Eni's distinctive MPD system is the e-nbd™ (Eni Near Balance Drilling). This system consists of an innovative drilling process that maintains constant bottom hole annular pressure at all times. The system does not require that mud circulation be stopped and compensated with a back up pressure.
The e-nbd™ is assisted by a proprietary system for continuous circulation that is called e-cd™ (Eni Circulating Device). The e-cd™ system is composed of special subs that are positioned on top of each drilling stand. The number of required subs is defined by the length of the open hole section that is to be drilled with continuous circulation. The system is completed by a dedicated manifold that is positioned on the rig floor that automatically diverts mud flow from the Stand Pipe Manifold to the subs.
e-nbd™ through the e-cd™ System ensures a continuous MPD process, without any "transient" time.
This paper presents this innovative system and the achieved results. It reports a summary of the applications performed to date, including some offshore applications from floaters, as well as the major benefits of the system.
The Rapid Growth of e-Learning in the Upstream Petroleum Industry
Authors: Donohue David A. , Donohue Timothy D. , Kapela Jared M. 
Published: October 2011

Abstract
The use of e-Learning to train upstream petroleum technical specialists has grown substantially in the past five years. In this paper we summarize how that rapid growth has occurred among the 80 company users of a major E&P e-Learning resource, list those practices that lead to the most effective use of e-Learning and indicate how this form of learning is reducing the overall cost of training.
By analyzing the monthly e-Learning usage data of 80 worldwide corporate users and the usage practices of the "best users," we are able to recommend how e-Learning can be most effectively implemented and used in conjunction with challenging simulations to build competency more rapidly.
e-Learning can significantly reduce training costs, and allow classroom courses to focus less on lectures and more on practical assignments and simulations so as to enhance learning and build performance competencies.
Maximization of Oil Mobility within a Hydrocarbon Reservoir for Elastic Wave-based Enhanced Oil Recovery
Authors: Jeong Chanseok , Kallivokas Loukas F. , Huh Chun , Lake Larry W. 
Published: October 2011

Abstract
Elastic wave-based enhanced oil recovery (EOR) has been proposed and used as a low-cost EOR method. Strong wave motions were reported to be able to mobilize oil still remaining in previously bypassed zones. This paper discusses the feasibility of inducing resonance-like wave motion within an oil reservoir in order to maximize wave-based EOR. To this end, a novel mathematical algorithm was developed to determine the optimal conditions of wave sources that can maximize the wave motion within an oil reservoir while minimizing, if desired, the vibrational disturbance in the neighboring formations. The optimized wave sources can generate strong wave motion within an oil reservoir, thereby potentially allowing the oil ganglia trapped in rock pores to overcome the strong capillarity between the droplets and the rock matrix.
Numerical experiments were conducted to identify the unknown optimal time signal information of wave sources that can lead to the maximum kinetic energy or maximum acceleration within an oil reservoir. These numerical experiments consider realistic geometries and material properties of a hydrocarbon reservoir, as well as multiple wave sources located on the ground surface. We demonstrate that optimized time signals can result in constructive interference of wave motion within a targeted hydrocarbon reservoir. We show that such signals can be either monochromatic, where the excitation frequency corresponds to one of the discrete reservoir amplification frequencies, or can even be transient.
Overall, when the formation's characteristics are known, our method allows one to prescribe the necessary waveforms that maximize particle motion within the reservoir.