bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Simplified Method to Estimate Peak Casing Pressure during MPD Well Control
Authors: Chirinos Jose E. , Smith John R. , Bourgoyne Darryl 
Published: October 2011

Abstract
The constant bottom hole pressure (CBHP) method of managed pressure drilling (MPD) has important advantages versus conventional drilling, especially for well control. One is the ability to stop formation flow by increasing casing pressure while continuing to circulate rather than shutting in the well. A requirement for applying this method is for the pressure rating of the rotating control device to exceed the maximum casing pressure experienced during kick circulation.
This peak casing pressure is typically estimated by applying the gas law for a single bubble calculation or by using a computer simulation. This paper describes a new, step wise method that combines gas law calculations with empirical knowledge developed by Ohara (1996) of gas distribution and velocity based on full-scale kick circulation experiments.
The new method was applied to predict the maximum casing pressure expected during kick circulation for a range of well geometries, kick sizes, fluid properties, and circulating rates. The results of applying the new method were compared to single bubble calculations, transient multiphase computer simulations, and the actual pressures recorded in test wells.
The proposed method provides a simple, potentially more accurate way to predict the maximum casing pressure during circulation of a gas kick. Consequently, it can be used to determine the surface equipment pressure ratings and formation fracture resistance required to provide the desired kick tolerance to drill safely using MPD equipment for well control.
BMPs for Minimizing Environmental Impacts: A Resource for Communities, Government and Industry
Authors: Mutz K. M. , Rice K. L. , Walker L. , Palomaki A. C. , Yost K. D. 
Published: October 2011

Abstract
The Intermountain West Oil and Gas BMP Project (BMP Project) is a collaborative effort of the Natural Resources Law Center and its partners, including the Environmentally Friendly Drilling Program. The BMP Project has developed a comprehensive, free-access, searchable, web-based database of oil and gas best management practices (BMPs) for the Intermountain West (http://www.oilandgasbmps.org). The database includes over 7, 000 BMPs addressing air and water quality, soils, visual aesthetics, health and safety, wildlife, and other resources. These BMPs are currently required or recommended for responsible resource management by various levels of government, communities, conservation organizations, industry groups, or individual companies. The project website includes resource pages on development issues and controversies as well as case studies of industry efforts to minimize environmental impacts. A community page illustrates community-industry efforts to negotiate, rather than litigate the best options for rational development. The BMP database focuses on source materials regarding both conventional and unconventional development from the Intermountain West states of Montana, Wyoming, Utah, Colorado and New Mexico. The website resource pages also focus on the Intermountain West, but draw on information from unconventional gas developments beyond this region.
This paper describes the Intermountain Oil and Gas BMP project resources and addresses the role of BMPs within the range of law and policy options available for facilitating development while promoting environmental and community health and safety. The paper also summarizes what is known of the efficacy and cost effectiveness of BMPs.
Communities embrace development for the economic benefit it brings to their areas, but both communities and conservation groups vigorously work to prevent oil and gas development from recklessly disrupting their lives and destroying sensitive environments. Governments consider new means to control impacts while still promoting development. Many companies work to balance cost effective production with practices that protect the environment and the communities they impact. The Intermountain BMP project helps these stakeholders identify appropriate practices for minimizing impacts to surface resources during planning, design, construction, drilling, operations, reclamation, and monitoring. BMP Project resources can also help stakeholders learn to work together to fuel the country's energy requirements and address the economic needs of communities without sacrificing the quality of their environment.
LWD for Well Placement and Formation Evaluation Towards Completion Optimization in Shale Plays
Authors: Kok Jeffrey , Shim Yen Han , Tollefsen Ed 
Published: October 2011

Abstract
Unconventional shale plays are characterized as low porosity and low matrix permeability reservoirs. In addition, they lack an obvious seal or trap, are of large regional extent, and understood to be heterogeneous in nature.
Due to this understanding, vertical, pilot wells are commonly drilled to evaluate rock properties and determine horizontal shale gas targets. Horizontal wells are drilled then completed by means of hydraulic fracturing to maximize reservoir contact and enhance production performance.
To position the lateral production borehole within the defined target, geosteering is commonly performed using a single averaged gamma ray measurement. In the initial development phases, this is often perceived as the most economic means for measuring and steering the production hole.
However, acquisition of sufficient LWD data demonstrates that by relying on a single measurement, structural models can be made to present several different possible correlation scenarios. Obviously, a non conclusive structural interpretation will negatively impact any efforts of evaluations for efficient field development. While, averaged resistivity measurements may be utilized as an additional correlation reference to complement gamma ray, improvements to correlation accuracy are best achieved with azimuthal images such as density, resistivity or gamma ray images. Real-time image measurements are used identify thin layers while cutting up or down dip as well as structural dip authentication along the well trajectory to provide a high level of confidence in the interpreted geosteering model.
Effectively, an accurate structural model is also an effective tool to design completion, correlate formation properties and refine target sizing while providing the foundation for formation evaluations.
This paper illustrates how correlations using only an averaged gamma ray measurement for structural modeling and steering of a production hole can result in multiple interpretations. This uncertainty is a potential cause of inconsistent reservoir interpretations and low or varied production across a given field.
In comparison, acquiring sufficient measurements while drilling for formation evaluation, and well placement can be applied to deliver consistent production results and provide a common platform for completion design practices.
Pressure Transient and Production Data Analysis of Horizontal Well in Unconsolidated Formation in Frade, Brazil
Authors: Pan Yan , Ewy Russ , Ringe Don , Kamal Medhat M. , Affinito Ralph , Sotunde Oluwole 
Published: October 2011

Abstract
Frade Asset is a medium-heavy-oil field located in the Northern Campos Basin, approximately 75 miles offshore from Rio de Janeiro, Brazil in 3500 ft water depth. The structure is a low relief anticline with two main fault blocks consisting of four stacked unconsolidated reservoirs. First production started in June 2009, and field development target peak production is 80, 000 barrels of crude oil per day. Currently, the field is producing from 9 horizontal oil wells with 3 vertical water injection wells to maintain reservoir pressure. Continuous well monitoring and reservoir characterization is the key to cost-efficient development in this deep-water subsea field. Therefore, most wells in Frade are equipped with permanent down-hole gauges for reservoir surveillance.
In this paper, we discuss the impact of three efforts on field performance: 1) monitoring the pressure and production data from horizontal wells since first production, 2) the real-time pressure transient analysis (PTA) of a series of buildup tests, and 3) the transient study combined with long-term production data analysis (PDA). The study results provide insight into formation quality and the change of well conditions with time. The estimations of current drainage area, average reservoir pressure, and original oil in place help to optimize the field development plan. The impacts of pressure-dependent oil properties and rock compaction were also studied, and the first quantitative evaluation of pressure-dependent permeability/porosity reduction was performed using both long-term dynamic well data and laboratory core experiment results. The applications of PTA and PDA in Frade showed that using current advanced technologies properly can yield valuable well and reservoir information from well pressure and rate data.
The positive impact of focused efforts to measure and analyze pressure transient and production data, and to use pressure-dependent permeability and porosity values in managing a large asset, demonstrated best practices that may be followed in other oil and gas fields.
A Multiple-Porosity Model for Evaluation of Giant Naturally Fractured Gas Sandstone Reservoirs in Bolivia
Authors: Sivila L. J. , Graves R. M. , Aguilera R. 
Published: October 2011

Abstract
A multiple-porosity petrophysical model that honours heterogeneity and the complex geologic characterization of a giant gas reservoir in Bolivia has been developed. The model handles five different porosity types: macrofracture, low conductivity fracture, microfracture, shale, and dispersed and intergranular porosity. Geological evaluation indicates that these porosities have some degree of connectivity. Due to the various porosity components, the model permits a more accurate estimation of the cementation exponent (m) and provides a better understanding of the gas storage and water saturation distribution in the reservoir. The model also has the capability to account for lithological variations throughout the field.
There is a wide variety of available models for estimating petrophysical properties, but none was found that could represent the available data for this field realistically. The Borai correlation, developed exclusively with data from Abu Dhabi carbonate reservoirs, has been used in the past to evaluate the Bolivian reservoir. As a consequence, we undertook the petrophysical analysis from a different perspective and developed the proposed model. Taking into account the various porosity types, lithology and structures depicted in the field geological characterization has been essential to develop the solid petrophysical model presented in this study. This in turn is an important aid for understanding reservoir behaviour.
The proposed multiple-porosity model allows sound characterization of the Bolivian gas reservoir considered in this study because it is strongly linked to the field geological heterogeneity. We anticipate that given the flexibility of the model, it will be applicable for characterization of sandstone reservoirs with similar characteristics in other regions around the world.
Assessment and Prediction of Erosion in Completion Systems under Hydraulic Fracturing Operations Using Computational Fluid Dynamics
Authors: Farahani Rezsa , Lastiwka Marty , Langer Doug , Demirdal Barkim , Matthews Cam , Jensen John , Reilly Adam 
Published: October 2011

Abstract
High rate injection or production of fluids with sand particles places wellhead components and downhole assemblies at risk of erosion damage. Depending on the severity and location of the material loss, this may pose a significant well loss or blowout hazard. For this reason, assessment and mitigation of erosion can be critical for such applications.
In this work, Computational Fluid Dynamics (CFD) was used in conjunction with erosion models to assess the erosion damage characteristics associated with the operating conditions and equipment for a high-rate, shale gas reservoir fracturing application. The work was based on the severe erosion damage experienced by EnCana as a result of high rate hydraulic fracturing operations performed in horizontal shale gas wells at their Horn River, BC field development. Material losses were observed within the wellhead equipment as well as in the LTC couplings of the production casing string near surface in several wells. CFD models were developed for the existing wellhead and wellbore geometries and used to simulate a range of hydraulic fracture operating conditions in an effort to predict the locations and degree of material loss in the components in each case. The models were calibrated with caliper log data and measurements taken from casing samples retrieved from several wells. The analyses suggested that well head system modifications, such as tubing head spool changes and use of spacer spools, could be effective in substantially reducing material losses in the tubular connections. In addition, sensitivity analyses were performed for different wellhead configurations and variations in the hydraulic fracturing parameters to determine the factors that likely had the most influence on the connection material losses. The results served to demonstrate that it is possible to use CFD with erosion models as predictive tools to identify locations of severe erosion in completion systems, and, when calibration data is available, to quantify the amount of material loss in wellhead and downhole components. This information can aid in designing optimum completions systems, and in defining operating conditions which can reduce the risk of equipment failure, potential blow-outs, and associated safety and environmental hazards.
Case Study: Successful Implementation of Driving Safety and IVMS Program
Authors: Gale B. R. , Trostel M. V. , Armitage D. L. , Mason M. A. , Bautista L. S. 
Published: October 2011

Abstract
Over 40% of all injuries and fatalities in the oil and gas industry are attributed to vehicular operations. Additionally, nearly one third of all fatalities were due to highway motor vehicle crashes as reported in a study of deaths in the industry between 20032008 (Retzer, et. al, NIOSH, 2011). For years the industry has tried a myriad of strategies to influence behavior, yet the risk of motor vehicle incidents (MVI's) remains a challenge for the industry and remains at the top of the list of hazards.
The proliferation of inexpensive sensors and wireless networks presented an opportunity to measure subtle patterns of human behavior that might be leading indicators of a driver's crash risk. Several years ago, Encana Oil & Gas (USA) Inc. (Encana) and a Denver based technology firm, Cartasite, teamed up to study driver behavior. The goals of this research were twofold:
profile the patterns of individuals against a large population of drivers, and attempt to influence those patterns to reduce risk, fuel consumption, and emissions.
The yearlong study program produced encouraging results and after analyzing the data, the decision was made to move forward with commercial product development. Encana has now deployed this technology on its entire fleet for over a year. A new Driving Safety Program has been put in place at Encana to effectively leverage the insights and data being collected. The impact of Encana's Driving Safety Program, presented herein, are encouraging and suggest that corporations may well be able to significantly reduce motor vehicle incidents and increase safety for field workers.
Prediction of Asphaltene Deposition in Porous Media by Systematic Upscaling from a Colloidal Pore Scale Model to a Deep Bed Filtration Model
Authors: Boek Edo , Fadili Ali , Williams Michael John , Padding Johan 
Published: October 2011

Abstract
We have successfully validated the Asphaltene Option in ECLIPSE, using an experimental data set from the literature. We compare our results with a previous Deep Bed Filtration simulation model of the same data. We find that the experimental data can be reproduced by using the surface deposition parameter α only. This provides an important simplification of the Asphaltene Option in ECLIPSE. Moreover, the values of α can be predicted from a pore scale colloid dynamics simulation model using the Stochastic Rotation Dynamics (SRD) technique. It turns out that the values for α obtained in the literature (Wang, 2001) and our own ECLIPSE results are consistent with the predictions from the SRD simulation model. This may give an advantage over other asphaltene deposition models available in the literature.
Benefits and Application of a Surface-Controlled Sliding Sleeve for Fracturing Operations
Authors: Shaw Joel 
Published: October 2011

Abstract
Recent improvements in fracturing technologies have allowed access to tight formations that previously were considered unprofitable. The most common of these technologies is a ball-drop-actuated sliding sleeve that allows operators to economically isolate and fracture ten to twenty zones in a single well. While these technologies have been well proven, there are still drawbacks such as:
Each zone requires a drop in the production string ID The zones must be stimulated beginning at the toe and ending at the heel Many applications require milling-out of ball seats after fracturing When possible to move sleeves after fracing, a workover is required.
A system has been developed to alleviate these limitations. This system includes well profile and isolation similar to the ball-drop sliding sleeve system but offers control of the sliding sleeves from the surface. This eliminates the cost and downtime of intervention. The system consists of an ICV (interval control valve) that has been optimized for fracturing applications. It is essentially an intelligent completion method that can withstand the extreme environment of a frac application. This allows the operator to frac the zones in any order, re-frac at a later date, close zones to allow pressure to build, eliminate water cut, and conduct transient pressure analysis of any zone without the necessity of a workover.
This paper discusses the use of surface-controlled sliding sleeves in frac-pack operations and the benefits that an operator can realize by installing the new sliding sleeves in tight formations.
Integrated Field Optimization Strategy Applied to an Offshore Water Injection Project
Authors: Chaban F. R. , Jordan L. C. , Annadorai K. M. , Wilkinson T. W. , Myers P. 
Published: October 2011

Abstract
Some of the most significant challenges faced with respect to the management of offshore water injection projects are associated with maintaining injectivity into the reservoir and with handling H2S produced due to reservoir souring. This paper presents the process followed and findings generated by a comprehensive review of a mature water injection project performed with the goal of delivering a coordinated operating strategy that would maximize the life of field revenues associated with water injection.
An integrated and comprehensive field optimization approach to maximize the whole-life value of the total asset was undertaken. Aspects covered included water injection system operating practices, mechanical design and integrity management of the injection system, the chemical treatment program followed for both the injection and production streams, and reservoir modeling and production management.
Recommendations resulting from this review were prioritized based on their impact on the whole-life performance of the asset, rather than the more common practice of separating the injection and production system reviews or the assessments of reservoir management and facility operation. Areas of particular benefit were identified in association with implementation of an active souring control strategy to reduce future risks to the production system metallurgy by sulfide stress cracking (SSC), a focus on integrity management of the water injection system to maximize long-term system availability, and the implementation of an inter-well water tracer injection program to enable the validation of current reservoir models and support the placement of future injectors and producers.
The combined approach employed in this review has enabled the Operator to adopt an operating strategy for the facility that will optimize operating costs and revenues through the remaining life of the asset. In addition to gains in future injection system uptime and the immediate optimization of the chemical treatment program, this review has also provided a basis to guide the evaluation of future reservoir management and field development strategies.
Application & Evolution of Formation Pressure While Drilling Technology (FPWD) Applied To The Gulf of Mexico
Authors: Blanco Yon , Turner Marcus 
Published: October 2011

Abstract
The emergence of formation pressure while drilling (FPWD) technology into the Gulf of Mexico (GoM) in 2004 was a step change for the industry. Over time the technology has been accepted by the industry as a reliable source for formation pressure and mobility measurements in real time for both reservoir evaluation and drilling optimisation. As the drilling frontiers are pushed, FPWD technology has advanced to meet the challenges. What have we learnt from this journey?
Today, the technology is applied in an increasingly diverse environment in the GoM with a focus on safety and data quality. This has been achieved by a perpetual learning and development cycle, advancing FPWD technology, logging while drilling (LWD) technology and refining processes. Advances in Real Time capabilities in LWD have also become critical to allow fast and founded decisions.
Examples are presented reviewing the applications and associated development of the technology over time to meet and exceed the GoM challenges:
Ultra deepwater, high pressure exploration in pressures exceeding 27k psi Reservoir evaluation in the heterogeneous Wilcox formation, where mobilities can swing from 0.5 to 50 mD/cP in a matter of inches, result in poor quality or long stationary times when fixed rates and volumes are applied blindly; however integration of a intelligent pretest design that automatically determines optimal rates and volumes in milliseconds can turn failure into success Sub salt drilling optimisation and pore pressure calibration Testing in severe pore pressure regression and/or highly depleted reservoirs with overbalances in excess of 7k psi. Refining electronics and pretest motor controls opened up new opportunities for operators to determine magnitudes of depletion previously unobtainable Shallow, unconsolidated or highly overpressured formations, which can lead to lost seals as the effective stress increase to the point of sand face failure, unique test designs perform low shock tests against the formation Well to well comparisons for vertical and lateral connectivity required pressure gauge development in high pressure environments &gt;20k psi
High spread rates in deepwater GoM require the efficient application of these new technologies. Through application of lessons learnt and technology advancements, Non Productive Time (NPT) can be minimized and data quality maximized.