bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Strategy for Seismic Facies Upscaling to the Reservoir Grid Scale
Authors: Duplantier O. , Hadj-Kacem N. , Vittori J. 
Published: December 2007

Abstract
We here present a new strategy for seismic facies upscaling to the reservoir grid. This methodology has been developed on the deep offshore Angola Girassol field data. Based on seismic attributes, it directly assigns facies associations and petrophysical properties to the reservoir model. The new strategy divided in two steps proposes to be more consistent with the petrophysical data and to ensure a better geological facies organization and a better facies continuity than classical upscaling approaches.
Step 1. Litho-seismic petrophysical properties, the dominant seismic facies and seismic facies probabilities are predicted. This creation is based on interpreted upscaled stratilogs (Facies Groups) and calibrated on all available petrophysical attributes.
Step 2. Seismic facies probabilities are upscaled from the seismic scale to the reservoir one. This upscaling is constrained by the dominant seismic facies and/or constrained by pseudo-petrophysical seismic cubes (Vclay, Porosity). Reservoir connectivity, geological organization and fine sandy channel definition are better preserved by this optimized upscaling than with a standard arithmetic average.
This new strategy, based on seismic attributes, allows a combined detection of geological facies organization and small scale internal heterogeneities as well as their preservation during the upscaling phase. It provides more suitable data for quantitative estimation of the uncertainties related to the reservoir properties.
Study on Flow Behaviors of Viscoelastic Polymer Solution in Micropore With Dead End
Authors: Yin Hongjun , Wang Demin , Zhong Huiying 
Published: December 2007

Abstract
The Upper-Convected Maxwell (UCM) model has been normally used to describe the rheological properties of polymer solutions. However, this model considers only viscosity and elasticity of a fluid without including the non-Newtonian power law behavior, a very important property to polymer solutions in reservoirs. Therefore, we present a Modified Upper-Convected Maxwell (MUCM) in this paper to take into account this property.
The steady flow mathematical model of MUCM fluids is established. The flow characteristics of viscoelastic fluids in the dead ends of porous pores in reservoirs are simulated numerically. The contours of velocity and stream function are drawn and micro-scale sweep efficiency is calculated quantitatively. The various regularities, corresponding to the change in visco-elastic properties of the fluid, are studied.
Numerical results show the visco-elasticity of polymer solutions is the main factor influencing sweep efficiency. With increasing elasticity, the flowing area in the dead end of pores is enlarged significantly, thus the area with immobile zones becomes smaller. Flow velocity is much larger than that for a Newtonian fluid, the sweep area and displacement efficiency increase as the elasticity increases. The visco-elastic nature of the displacing polymer fluids can in general improve the displacement efficiency in pores compared to using Newtonian fluids. This conclusion should be useful in selecting polymer fluids and designing polymer flooding operations.
Wellbore Cleanup Best Practices: A North Sea Operator's Experience
Authors: Fleming A. J. A. , Appleby R. R. 
Published: December 2007

Abstract
Wellbore clean up is a critical component of any new well construction. Failure to adequately clean the wellbore can cause major difficulties in running the completion resulting in large amounts of NPT with all the associated costs. Conversely, performing over-complicated clean ups to ensure success adds additional risks and unnecessary extra cost.
This paper examines an operator's experience with wellbore clean ups over a wide range of assets in the UK and Norwegian sectors of the North Sea. The operator wished to reduce the time taken by developing best practice guidelines. This would provide a common approach to wellbore clean up operations over all assets.
Using reports from 19 offshore wells completed between 2002 and 2004, the time taken during clean up operations was split between nine categories: ➢Running Tools➢Chemical Clean up / Displacement➢Pit Cleaning➢Waiting on Equipment➢Waiting on Weather➢Pressure Testing➢Non clean up Ops➢Safety Events➢Waiting on Permits
This allowed the causes of extended time to be identified and pinpointed the areas where most time could potentially be saved. Some of these were: ➢Clean up tool failures➢Over-complicated tool-strings➢Becoming stuck due to over ambitious toolstrings➢Rig equipment failures➢Incomplete tools being sent offshore➢Repeating of chemical clean up due to wellbore filters being full of mud/debris➢Delays while waiting for pit cleaning to be completed➢Lessons not being learned from other assets
These and other causes were further examined and discussed by operator staff in a workshop and vendor interviews. Guidelines were then developed by combining existing good practices from different assets and other industry experience.
Ultradeepwater Cementing: Challenges and Solutions
Authors: Mishra P. K. 
Published: December 2007

Abstract
Ultra Deep water drilling operation under Sagar Samriddhi Project started with two charted hire rigs Belford dolphin and Discoverer Seven Seas from Nov. 03. Since the commissioning of two rigs, total no. of 24 wells have been completed. This paper discusses real challenges faced during cementation of critical surface casing as well as liner and production casing. The maximum operating water depth was 3008 mt. Shallow water hazards like shallow water and gas flow also encountered during drilling of top hole sections. The lowest sea bed temp. Of 2 °C encountered in no. of wells. The narrow margin of pore and fracture. Pressure window necessitated the requirement of cement slurry of wt. not more than 11 ppg in many wells. The requirement of 5oo psi compressive strength of light wt. slurry within 24 hrs. time span at 15/20 ° C was one of the main challenges. All the above challenges were resolved using Schlumberger's PSD system combined with low temp. Gas Migration control additive, used for the first time in India. Proper cementing of liner more than 1500mts. Length with slurry wt. of 12.2 ppg was the biggest challenge faced during planning. Also the big temp. difference between the liner shoe and hanger top further aggravated the problem. However, the problems were solved using PSD system with proper Gas Migration control additive packages. Reduction of ECD during 7" liner cementation of well having high temp., was dealt effectively using high temp. Gas Migration control additive in well K1 X, the deepest well drilled in Indian Offshore. Production casing in four wells, having very narrow window of pore and fracture. pressure, perfect isolation was achieved using PSD system and proper Gas Migration control additive system.
Production Data Analysis—Challenges, Pitfalls, Diagnostics
Authors: Anderson D. M. , Stotts G. W. J. , Mattar L. , Ilk D. , Blasingame T. A. 
Published: December 2007

Abstract
Although production analysis (PA) for reservoir characterization is approaching the popularity of pressure transient analysis (PTA), there are few consistent diagnostic methods in practice for the analysis of production data. Many of the "diagnostic" methods for production data analysis are little more than observation-based approaches — and some are essentially "rules of thumb."
In this work we provide guidelines for the analysis of production data, as well as identify common pitfalls and challenges. Although pressure transient and production data analyses have the same governing theory (and solutions), we must recognize that pressure transient data are acquired as part of a controlled "experiment," performed as a specific event [e.g., a pressure buildup (or PBU) test]. In contrast, production data are generally considered to be surveillance/monitoring data — with little control and considerable variance occurring during the acquisition of the production data.
This paper attempts to provide a "state-of-the-technology" review of current production data analysis techniques/tools — particularly tools to diagnose the reservoir model and assess the reservoir condition. This work also identifies the challenges and pitfalls of production analysis — and we try to provide guidance towards best practices and best tools. To compliment this mission, we use relevant field examples to address specific issues, and we illustrate the value and function of production data analysis for a wide range of reservoir types and properties.
Modeling of Pig Operations in Natural Gas and Liquid Pipeline
Authors: Esmaeilzadeh F. , Mowla D. , Asemani M. 
Published: December 2007

Abstract
The use of pigs has become a standard industry procedure. This expanding demand has driven manufactures to produce a great variety of pig models. Most of the available knowledge is based on field experience. Hence, selecting the best pig, estimating its speed and required driving pressure, often involves some guesswork and consequently, a high degree of uncertainty. The pig is most effective when it runs at a near constant speed but will not be effective when it runs at too high speed. The typical speeds for pigging are about 1-5 m/s for on stream liquids and 2-7 m/s for on-stream gas (Cordell and Vanzout 1999).
In this work, the pig motion is modeled using Continuity, Momentum, Energy and State equations. These equations simultaneously are solved under unsteady state condition to obtain the pressure; pig velocity profile and the time that pig reaches at the end of the pipeline.
This information can help the operator to control speed of pig before the pig reaches the end of pipelines. The change area and elevation profile has been investigated.
The results are obtained for gas and liquid pipelines. The programs have been run for various values of time step and distance increment. The results are more accurate when time step and distance increment are getting smaller according to CFL (Courant-Friedrich-Lewy) condition
Natural Gas: Overcoming Limitations Toward Energy Supremacy
Authors: Harrison M. C. , Campbell P. , Coelho F. M. , Grecco C. , Ikeocha C. , Wang X. T. , Economides M. J. 
Published: December 2007

Abstract
The World, headed by North America, is shifting its energy focus towards natural gas for power generation as a substitute for coal and oil. Nuclear, which could be the obvious recourse, at least for now, seems to be losing to natural gas. Eventually, the "holy grail" of natural gas use must be its major contribution as a transportation fuel, not necessarily directly as compressed natural gas for engine combustion but indirectly, providing the necessary electricity in electrified transportation.
One of the clear advantages is that natural gas burns more cleanly and efficiently than other fossil fuels. Worldwide supplies are plentiful and diverse but with an imposing presence of Russia which houses the lion's share in proven reserves. Transportation has always been the issue and once recent major activities come to fruition (such as liquid natural gas, LNG) prices will be kept reasonable for decades. In the past few years, countries with traditionally modest gas reserves suddenly started declaring huge proven reserves to attract private investment. With the uncertainty associated with some of these claims it has become worthwhile to review all natural gas sources and the factors that will affect the supply, price and developments for the next 20 years. During the autumn and Winter of 2005-2006, the price of natural gas was driven to an unprecedented high (over $16/MMBtu) and had it not been for uncharacteristically mild winter in the United States the price would have escalated even higher. Emerging or speculated consumption by China and India, the always large U.S. energy appetite, along with maturing U.S. domestic production are the primary reasons for this predicament. The four-year run-up in natural gas prices is actually normal behavior for an economic or energy transitional period. However, serious energy-shortages loom on the horizon impacting more than just the price of a single commodity. Regulatory policies, ‘concerned’ environmental groups, and industrial inaction create choke points in the supply chain. Such manmade barriers, no matter how well intentioned, will needlessly generate energy woes and hardship for millions of consumers in the near future.
However, we are very bullish on natural gas and predict that it will emerge as the premier fuel for the world economy and we believe that supply, transportation and utilization challenges will be overcome by the industry and the consuming world.
Barnett Shale Hybrid Fracs—One Operator's Design, Application, and Results
Authors: Coulter G. R. , Gross B. C. , Benton E. G. , Thomson C. L. 
Published: December 2007

Abstract
The Ft Worth Basin Barnett Shale gas play has extended significantly from what was originally considered the ‘core’ area. The extension has taken activity South and West of Ft Worth, TX into Parker, Hill, Johnson, and other Counties. Operators in these areas have been using a number of different Barnett frac approaches. This paper discusses the Chief Oil and Gas, LLC (Chief) approach in these and the core areas. Based on work Chief published in 2004 (SPE 90891)1 it was shown that larger quantities of sand in Barnett fracs were beneficial. Continuing with this focus, studies were conducted in the core area with Hybrid Fracs. There have been numerous publications in the literature regarding Hybrid Fracs with no standard definition, other than some combination of slick water and gel stages with varying quantities of proppant. For the work reported here, we are defining our Hybrid designs based upon how the viscous gel is used. Some of the more recent Hybrid frac publications are referenced here2, 3, 4.
Chief has employed viscous gel slugs in Barnett Shale fracs in various designs. The C-Hybrid Frac design approach came from a three well study where we evaluated placing large quantities of sand using viscous gel slugs in one well (C-Hybrid Frac), a large quantity of slick water to place our ‘normal’ quantity of sand and the third well fraced with a ‘standard’ Chief slick water frac. The three well study was carried out on vertical Barnett wells in Tarrant County. Based on the results, one additional vertical Barnett well was fraced using the C-Hybrid Frac design. The results were sufficiently successful that the Hybrid Frac design was employed on horizontal wells in Parker, Hill, and Tarrant Counties of Texas. The design, application and results of this work are presented in the paper. Other applications of viscous gels in Hybrid type designs are also presented.
Forecasting Future U.S. Energy Needs
Authors: Skov A. M. 
Published: December 2007

Abstract
A reliable long range forecast of US energy demand would seem to be important for meaningful planning by government, industry, and academia. Yet actual forecasts are generally either short-term or poorly match long-term history or both. This paper describes a simple function that fits historical US data through many turbulent economic times from 1929 through 2002 with a correlation coefficient of 0.99. Population and real US Gross Domestic Product (GDP) are the only independent variables needed.
Some counterintuitive conclusions emerge. For example, price of oil is not a component of the history matching function. High prices have an offsetting negative impact on both energy demand and GDP. Hence, artificially increasing energy prices with a large consumption tax to reduce demand is a bad idea. Historically, high prices have jacked up inflation, too, which impacts real GDP and mitigates historical price effects. Inflation jumped four-fold with the high prices in the 70's and 80's.
During the 74-year period of history match, US energy demand grew fourfold, population more than doubled, and real GDP grew 12-fold. Oil and gas use rose from 18% of total commercial energy to 63%, and coal declined from 78% to only 23%, changes of staggering magnitude.
Use of this forecasting relationship for long-term projections of US energy demand also yields surprising results. For assumed long term real economic growth rates of one or three percent (the historical average), and generally accepted estimates of future US population growth, forecast energy demand, in the year 2100, are 52 quads and 366 quads, respectively, or either half, or four times, today's use, an astonishing range of outcomes for such a seemingly small difference in US economic growth rate. This suggests remarkable sensitivity of energy consumption to economic growth rate.
Other current and historical energy forecast methods and results, and possible applications to other economic entities, are also discussed and analyzed.
From Straight Lines to Deconvolution: The Evolution of the State of the Art in Well Test Analysis
Authors: Gringarten A. C. 
Published: December 2007

Abstract
Well test analysis has been used for many years to assess well condition and obtain reservoir parameters. Early interpretation methods (using straight-lines or log-log pressure plots) were limited to the estimation of well performance. With the introduction of pressure derivative analysis in 1983 and the development of complex interpretation models that are able to account for detailed geological features, well test analysis has become a very powerful tool for reservoir characterization. A new milestone has been reached recently with the introduction of deconvolution. Deconvolution is a process which converts pressure data at variable rate into a single drawdown at constant rate, thus making more data available for interpretation than in the original data set, where only periods at constant rate can be analyzed. Consequently, it is possible to see boundaries in deconvolved data, a considerable advantage compared to conventional analysis, where boundaries are often not seen and must be inferred. This has a significant impact on the ability to certify reserves.
The paper reviews the evolution of analysis techniques over the last half-century and shows how improvements have come in a series of step changes twenty years apart. Each one has increased the ability to discriminate between potential interpretation models and to verify the consistency of the analysis. This has increasing drastically the amount of information that can be extracted from well test data and more importantly, the confidence in that information.
Quantifying Resources for the Surmont Lease with 2D Mapping and Multivariate Statistics
Authors: Ren W. , Deutsch C. V. , Garner D. , Wheeler T. J. , Richy J.-F. , Mus E. 
Published: December 2007

Abstract
The McMurray formation consists of heterogeneous Cretaceous bitumen-saturated sands. The reservoirs are thick and laterally extensive in the main fairways. Many commercial projects are in the early stages of development. Resources too deep to mine are considering Steam Assisted Gravity Drainage (SAGD). Detailed high resolution 3-D geostatistical modeling is useful for individual well pair or pad flow simulation, but is neither practical nor necessary for resource assessment over large areas.
This paper presents a practical and tested methodology for resource assessment in the Surmont Lease. The uncertainty in over 30 correlated variables is calculated on a dense 2-D grid using all available information including wells, seismic and geologic trends. The correlation structure between the variables is modeled under a multivariate Gaussian model. The local distributions of uncertainty have been checked with cross validation and with more than 100 new wells drilled during the last two drilling seasons. Resource uncertainty over the entire lease area and a number of arbitrary development areas is derived from the 2-D maps of uncertainty. A combined P-field / LU simulation approach is used; the global uncertainty is consistent with the local uncertainty.
Effective Software Practices To Leverage Software Development Process in Sand-Control Engineering Software—A Case Study
Authors: Li J. , Chok P. 
Published: December 2007

Abstract
The quest by E&P companies and their service providers to gain a competitive edge through technology is driving a demand for higher standards in engineering software. Time to market is a critical success factor and is often viewed as contradictory to higher standards and other factors such as limited resources and budgets. An optimum approach to engineering software development can successfully satisfy both time-to-market and budgetary requirements while continually raising standards.
This paper will discuss software practices that have proven effective during a full oilfield engineering software application development life cycle. Although the process activities – including specification, design, development, testing and deployment – were conventional, they were sequenced in a non-conventional manner and augmented with techniques such as risk management, use cases analysis, software modeling and configuration management.
The paper presents a case study that illustrates how these practices were used in a sand control engineering software development project to successfully design and remodel an existing horizontal gravel pack spreadsheet application into a standalone desktop application. The new application provides a user-friendly interface to design and analyze gravel transport for solids of varying density in Newtonian fluids. A computation engine was developed as a plug-in component to perform various computations during the gravel packing process. An object-oriented architecture and framework were designed and built to avoid having to rebuild every new application from scratch. The authors will explain how the system was built and extended to incorporate new capabilities and how adopting optimized development practices has enabled reuse of software components in new applications and increased both the standards and cost-effectiveness of engineering software development.
Nondamaging Drilling Fluid Enhances Borehole Quality and Productivity in Conventional Wells of Mehsana Asset, North Cambay Basin
Authors: Mandal N. G. , Jain U. K. , Kumar B. S. Anil , Gupta Ashok K. 
Published: December 2007

Abstract
Mehsana Asset of ONGC, in North Cambay Basin in India, emphasizes on increased oil production with the use of new technologies. Non Damaging Drilling Fluid (NDDF) is the basic part of this paradigm shift. Application of NDDF is the most direct method for controlling formation damage during drilling. NDDF was introduced in Linch field of the Asset for drilling of pay zones. The paper covers formulation, field optimization and application of NDDF in three wells of Linch field and subsequent application in North Kadi field. Laboratory results as well as field behaviour and parameters of NDDF along with drilling parameters and production testing results are discussed. The paper also touches the constraints in application and their solution by coordination and ingenious use of available resources. Field optimization of NDDF formulation has shown encouraging results in terms of compatible mud parameters. No complications were faced while drilling and testing. Gauged holes have shown good quality of logs. The wells have given a distinctively increased productivity in terms of oil production with instant activation.