bluuebunny/crossref_metadata_2025_split huggingface dataset:
Accurate and Fast Method for Predicting Actual Top-of-Cement Depths in Eccentric Wellbores
Authors: PKS Sairam , Savery Mark , Morgan Ronnie 
Published: February 2010

AbstractIt is often perceived that a cementing operation is the last step in the drilling process, but any cementer can tell you that cementing is the first step to a successful completions process. Proper displacement of mud during cementing operations is not only critical for successful zonal isolation, but also for achieving asset-management objectives for increasingly difficult-to-reach hydrocarbon reservoirs. One of the challenges in these complex wells is to provide uniform cement coverage across the entire zone of interest, especially in targeted zones where casing or liner is decentralized (off-center). In these situations, an uneven pressure differential from decentralization causes uneven flow of cement. The result is a much different top-of-cement (TOC) on the narrow side of the annulus versus the wide side of the annulus. Real-world negative effects of this phenomenon can include annular pressure build-up, the necessity of remedial squeeze work, and even well abandonment.A better understanding of fluid movement through the eccentric annuli can help predict the true TOC around decentralized casing. Therefore, a first-of-its-kind flow-predictor program was developed with the capability to accurately predict the TOC and corresponding fluid velocities for a three-component mud-spacer-cement system in eccentric annuli. It is based on a generalized mathematical model for pressure-drop prediction, developed using more than 1,700 experimental data points in physical models mimicking that of actual downhole geometries. Experimental data consisted of narrow and wide-side flow rates for 14 different fluids, within a density range of 8 to 21-lbm/gal, circulated in standard oilfield pipe and hole configurations ranging from 4.5-in. × 6.5-in to 9.625-in × 12.25-in. Standoffs varied between 12 and 82%. Yield point, viscosity, and shear thinning indices of these fluids varied between 0 and 50-lbf/100ft2, 1 and 157-cp, and 0.4 and 1, respectively. Various simulations are shared to reveal the properties and parameters required to help achieve uniform flow around the annulus and a balanced TOC.
Multi-Stage Hydraulically Fractured Shale Gas Rate Transient Analysis
Authors: Bello Rasheed O. , Wattenbarger Robert A. 
Published: February 2010

Abstract
The common completion technique in horizontal shale gas wells is by hydraulically fracturing in multi-stages. In this paper, a linear dual porosity model is used to approximate the shale gas completions with a horizontal well and multiple hydraulic fractures. Five flow regions are identified with this model. Region 1 is transient drainage in the fractures, Region 2 is simulataneous drainage from matrix and fractures or bilinear flow, Region 3 is the infinite-acting case, Region 4 is transient drainage from the matrix and Region 5 is the boundary-dominated flow case. Derived equations are presented for each of the flow regions.
It appears that field production data exhibit Region 4. This transient flow regime is the only flow regime available for analysis in many wells. A skin effect for Region 4 is observed in many wells and described in this paper. A procedure is presented in this paper to analyze field data and is illustrated with a sample case..
Risk Analysis and Decision Making in Relative Permeability Modifier Water Shut-Off Treatment
Authors: Awad Quosay , Ibrahim Abdelhalim , Salah Ramzi , Bakheet Ahmed 
Published: February 2010

Abstract
In the last few years, water shut off (WSO) treatments in production wells have started to become as a part of standard well service. Decision making, taking into account the uncertainties of reservoir and well data, is a difficult job with regard to WSO treatment especially with the current high oil price.
The success of any relative permeability modifier (RPM) treatment is depending on the pre-treatment reservoir and well production parameters. The uncertainty within these parameters leads to improper prediction of the post treatment condition and consequently a wrong WSO treatment decision may be taken.
An RPM WSO treatment evaluation model was developed based on Monte Carlo simulation and a developed radial flow equation. The model predicts the post-treatment water cut and production rates specifying a range that extends from minimum output value to a maximum value in order to alienate any chances of associated risks. The simulation inputs and results are also illustrated as probabilistic distributions providing a complement to the previously cited production results. Decision tree model is used to choose the best option among different RPM WSO treatment scenarios.
Case Histories: Real-Time Downhole Data Increase Drilling Efficiency
Authors: Sharma Nitin , Srinivasan Ananth , Hood James 
Published: February 2010

Abstract
With current trends in exploration, drilling operations are becoming more complicated and cost-intensive. Although the focus is often on reducing non-productive time (NPT) and invisible lost time (ILT) in these high-tech wells, little time is spent on benchmarking for the time taken during common drilling and non-drilling procedures.Today’s downhole MWD systems are able to transmit information in real time, such as weight on bit (WOB), torque on bit (TOB), downhole azimuthal bending moments, downhole RPM and drilling dynamics diagnostics. However, decisions in wells ranging from simple to complex are still made using traditional surface-acquired drilling data. This paper includes cases where the use of downhole drilling data increases drilling efficiency. Six case histories describe four different applications where a downhole optimization sub’s (DHOS) real-time data was used to improve drilling operations.
New Integrated Approach for Diagenesis Characterization and Simulation
Authors: Pontiggia M.. , Ortenzi A.. , Ruvo L.. 
Published: February 2010

Abstract
The study of the diagenetic processes is a fundamental step to achieve a more accurate and reliable prediction of flow performance, as diagenesis alters the original relationships between depositional facies and petrophysical properties. Thence, a quantitative integration of all data and available analysis is a key-factor to obtain a realistic reservoir model.
A new integrated approach for diagenesis characterization and simulation is here presented. An application case was performed on the silici-clastic Egyptian reservoir of Baltim starting from quantitative diagenetic data.
Chlorite content, which is here strictly related to grain size, affects the overall reservoir permeability. Particularly, "pore filling" type chlorite is responsible for the flow performance deterioration.
A relationship between diagenesis and log data was defined using density and spectral gamma ray (thorium) logs as predictors of pore-filling chlorite. A good relationship was also observed between grain size and the previously defined log-facies from multivariate statistical processing (cluster analysis), enabling us to assign a well defined depositional meaning to each of them.
The right evaluation of the petrographic-diagenetic input represents an excellent "starting line" for the following phases.
First, a traditional reservoir workflow (pre-diagenesis characterization) has been carried out testing different geostatistical facies simulations approaches (Sequential Indicator Simulation, Object Based Approach, Truncated Gaussian Simulation, Pluri Gaussian Simulation and Multiple Point Statistics). Then, a new methodological workflow for post-diagenesis reconstruction has been implemented, using a matrix that combines sedimentological information and diagenetic indicator at wells. Finally the petrophysical parameters have been simulated classically according to the characteristics of each post-diagenesis facies.
The results, compared to well test permeability and analysed with the flow simulator, show a good to very good match with the measured data. The match quality is clearly dependent on the mutual consistency of the facies distribution and the conceptual sedimentological model conditioning diagenetic effects.
Enhance Digital Oil Fields by Plugging the Technological Capability Gap
Authors: Holdaway Keith R. 
Published: February 2010

Abstract
The oil and gas industry needs to plug the capability gap with pertinent technology that embraces the current trends to improving productivity. Digital oil fields have to engage the geosciences community and the business decision makers, surfacing knowledge from the plethora of accumulated data, both real-time and historical.
Solutions must integrate not only the data, but extant applications and physical monitoring systems, and enable efficient collaboration between these facets to perform tasks faster and with more effectiveness and efficiency. With improved workflows and computing potential, it is now possible to ascertain the risk assessment and quantification of uncertainty inherent in improving productivity. The cost implied by poor predictions has to be mitigated by improved integration of disciplines and data fusion by adopting soft computing methods such as neural networks, fuzzy logic and probabilistic reasoning instilled into efficient workflows and processes. Reservoir characterization is a crucial player in modern reservoir management, and can lead to improved and timely reservoir decisions and this leads to heightened value of the oil and gas assets.
This paper draws upon a case study that ameliorates the path to knowledge that is derived from available data. Let us look at a reservoir surveillance management solution that embraces a predictive detection and alerting solution to improve production forecasting and planning, and so assist in managing corporate risks and investments. Also, as we walk through a digital oil field workflow, we can focus on some of the soft computing techniques such as neural networks and fuzzy logic that lend credence in reservoir characterization.
Health Risk Management
Authors: Shehata Elsayed Saad 
Published: February 2010

Abstract
Occupational Health (OH) Management is the management process, through which corporate resources are organized and used to promote well-being and prevent, or minimize, the adverse health impact of work on personnel and contractors. Failure to control occupational health risks in the workplace can result in a wide range of effects, from general worker under performance to premature deaths. It is also recognized that good occupational health performance is not only ethically sound, but it also makesgood financial and business sense. It is also an essential component of the HSE Policy.
Health Risk Management is a modern fast moving subject as it covers all aspects of risk associatedwith the worker environment and its affect on health.Today's Occupational Health and Safety Professionals take the pro-active approach by trying to prevent ill – health and accident beforeit happen.
Petrobel developed and implemented a new Health management system with reference to Egyptian Legislation, Eni E&P (shareholders) standards and industry best practice.
This Occupational Health Management System includes: ▪Medical Assessment Programe▪Fitness to Work – Minimum Medical Standards▪Catering & WaterHygiene & Quality Standard▪Minimum Equipment Standards for Petrobel Medical Facilities
Propped Fracturing with a Novel Surface Cross-linked Acid in High Temperature Deep Carbonate Formation
Authors: Ding Yunhong , Li Yongping , Xu Yun , Cheng Xingsheng , Wang Yonghui , Zhang Fuxiang , Jianxin Peng 
Published: February 2010

Abstract
Acid fracturing, as a conventional and effective stimulation method, has been widely used in carbonate formation. But because of serious acid leak-off and rapid acid/rock reaction speed, the length of effective acid etched fracture is always restricted, even the high viscosity acid and emulsified acid were applied; besides, the effective duration of etched fracture was short, especially in deep well. The propped fracturing can supply longer fracture and long-term effective duration, but its ability of connecting natural fracture or fissure is poor because the fracturing fluid is unreactive with the formation. So the propped fracturing with a novel surface cross-linked acid (SXA) is proposed, because it can not only realize long fracture length/deep penetration, but also connect more natural fracture/fissure to maximize the permeable area as possible.
In order to realize the technique, a novel temperature-stability and shearing resistance delayed cross-linked acid (SXA) was developed to qualify for the fracturing treatment. Meanwhile the effect of HCl on one high strength ceramic proppant was also studied, and the results showed the crush resistance and conductivity of proppant is unaffected. So the SXA and the acid- resisting proppant provide the basis for acid propped fracturing, and a comprehensive fracturing technique was developed.
Acid propped fracturing with SXA was processed in the carbonate formation with depth &gt; 5000m and temperature &gt;140℃. A volume of 36.2m3 proppant was successfully pumped into the formation with the maximal proppant concentration exceeding 450kg/m3. The net pressure matching indicated that the propped fracturing created long conductive fracture and realized deep penetration. The new technique provided a new and broader option of carbonate stimulation.
Improving HSE Contractors performance
Authors: Shehata El Sayed 
Published: February 2010

Abstract
Today’s oil & Gas industry is showing an increasing tendency to have more dependency in outsourcing the most for achieving its goals. The most evident case can be appreciated in areas that are generally executed using specialized contractors and manpower.
Petrobel places a continuing emphasis on the management of health, safety and environmental protection implemented by the Contractors working in its sphere of operations in order to ensure that all reasonable protection is provided to preserve personnel, plant, equipment and the environment.
One of the key points is finding the right balance between the expected performance by the contractors and the amount of resources and time required to put in place by the contracting company to maintain a sustainable continuous improvement process to achieve an integrated good HSE performance by both parties.
Good HSE reputation is ringing the bells all over around the world and this means reliability and profit wins or losses. Today’s stock market is more sensible than ever and it is impossible to say that we are achieving well when our contractors are poorly performing.
Contractors HSE Management is established to ensure that a standard and uniform approach is adopted by Petrobel for the evaluation of Health, Safety and Environment Management Systems developed and implemented by Contracting Companies at various phases of business.
Contractor HSE Management System should help adopt a common strategy by Petrobel for dealing with different categories of contractors in the aspects of HSE Management from the pre-qualification stage up to the completion of contract.
Contractors should be urged to develop their own HSE Management Systems in proportion with the risks encountered during a contract period, so as to reduce the risks to as low as reasonably practicable level, taking into account the cost benefit to achieve this objective.
The Key Drivers Determination for Offshore Plants Decommissioning and Abandonment Cost Estimate
Authors: Michetti V.. , Nicotra G.. , Dresda F.. , Tignanelli A.. , Moore W.. 
Published: February 2010

Abstract
In the last 10 years the Oil & Gas Industries have begun tackling the complex issues related to the end-of-life of Upstream Assets Decommissioning. Theses are especially relevant for offshore activities due to their environmental impact and the elevated costs.
The introduction of the SFAS 143 principle in the United States, which defines the criteria for Decommissioning and Abandonment costs of production assets allocation and establishment, for companies listed on the New York Stock Exchange, requires such companies to report Abandonment funds.
In Eni E&P a tool for decommissioning cost estimating (property of Eni E&P Division) was required in order to evaluate the abandonment fund quickly and with a good accuracy.
The work to be performed was: to inspect all the techniques for topside total removal, abandonment and removal of substructure and sealines, taking into account local and international legal constraints, then to evaluate cost–estimate key drivers. A unique cost breakdown structure has been defined for all methodologies in order to guarantee the congruity of the estimate: vessel, personnel and equipment are the three cost parameters used to evaluate the main cost elements such as Mobilization/Demobilization, Survey Pre/Post Removal, Flushing and Clean Up, Equipment and Personnel for Removal, Engineering & Management and Onshore Final Disposal.
Information about techniques, field of operation, advantages/disadvantages and unit costs have been gathered by analyzing Eni’s experiences, through a benchmarking of the most important international competitors, and through experts’ opinion.
Evaluation and Field Optimisation of Kinetic Hydrate Inhibitors for Application Within MEG Recovery Units, Gas Condensate Field, Mediterranean Sea
Authors: Allenson S. J. , Scott A.. 
Published: February 2010

AbstractThe most common chemical treatment for hydrate formation is the use of thermodynamic hydrate inhibitors (THI), which act to shift hydrate equilibrium conditions toward higher pressures and lower temperatures. On systems where a THI is needed on a continuous basis, regeneration systems have been developed to lower the cost. The most common regeneration systems are methanol recovery and MEG recoveryunits (MRU).While these recovery units can lower the cost of a THI treatment program, the large volume of THI needed for most operations remains a major problem for many operators. A new method to prevent hydrate formation that can significantly reduce the amount of THI needed is using a Kinetic Hydrate Inhibitor (KHI) in combination with a THI.This paper will discuss the laboratory evaluation of KHI chemicals, deployment of KHI within a MEGstream and optimization of a combination of MEG/KHI when applied to an offshore gas/condensate field in the Mediterranean Sea.The objective of the trial was to apply the selected KHI and reduce the MEG injection rate as far as the MEG injection system would allow. The operator imposed a 50% reduction in MEG rate as a target for a successful trial of the KHI chemical. During the trial it was possible to pass the initial target reduction of MEG and in fact a reduction in the MEG rate by 70% was recorded. During the trial unplanned shut downs (duration 3 days) occurred but even under these conditions the KHI was still effective.The lessons learned during the selection and field optimization will be presented along with the economic impact that the reduction in MEG has made to this operation. The implications of these findings will be outlined in terms of impact on Capex projects such as the footprint/capacity of the handling/storage and recovery units. The impact that KHI application can have during the OPEX phase where it will also be shown such as de-bottleneck existing systems where salt loading and/or higher than expected produced water volumes are experienced.
Manufacturing Light Oil from Heavy Crude Ratqa Field, North Kuwait
Authors: Luzardo M. Luis C. 
Published: February 2010

Abstract
Heavy Oil from North Kuwait does not have an intrinsic commercial value by itself. The crude is estimated to have an API in the 11-18 API range and high sulfur of &gt;5% wt., which makes extremely difficult the processing operation in a conventional crude oil refinery. Notwithstanding, currently there are two options to make this crude marketable: By diluting or Blending the Heavy Oil (11 API) with a much lighter crude oil to produce a blend to be placed in the open market, orBy processing the Heavy Oil in Upgrading complexes and, depending on the selected upgrading scheme, produce a range of upgraded crude oils which vary in API from 16 to 35 and have sulfur contentbetween 0.1 and 3.5 % wt.
The first option, blending the Heavy Oil with a much lighter crude oil, has the disadvantage of degrading a high value light crude oil (Between 80 and 140 mbopd of 46 API Light Crude) to produce a lower value blend (Between 140 and 800 mbopd of 16 to 30 API).
If the Heavy Oil (11 API as the worst case) is upgraded to 31 API and sold, and the Light Oil (49API), which would be degraded to make the blend is sold separately, the revenues would be very high.
kOC is studying all possible disposition options for the HO from North Kuwait. Only two options (Blending and Full Upgrading) are compared in this paper, but other options such as Refining the HO in Kuwait existing and/or new Refinery, using the HO as fuel to generate electricity, etc., will be considered and studied in detail before a final decision is made by KPC.
The technical challenge for studying this option (Upgrading an 11-15 API crude to 31 API) is to find the optimal upgrading technology and to integrate an optimal upgrading scheme capable of manufacturing an upgraded crude oil with a commercial market value, as one option to dispose the Heavy Oil. That upgrading scheme is presented, in this paper, as an option for disposition of the HO from North Kuwait.
The significance of the studied options for KOC as a National Oil Company would be the technical contribution, to the overall project economics, arising from the combination of upgrading technology with the optimum upgrading processing scheme capable of producing a viable commercial option.
Determination of the Aquifer Activity Level and the Recovery of Water Drive Gas Reservoirs
Authors: Li M.. , Yang W. J. , Xiao Q. Y. , Liu S. C. , Zhang J.. , Peng G. M. 
Published: February 2010

Abstract
The judgment of the aquifer activity level and the recovery of waterdrive gas reservoir are intricate and crucial. The paper is to develop a new criterion to determine the aquifer activity level and a new chart method demarcating the range of recovery variation. In the first place, reasoning and defining the new criterion of the determinate aquifer activity level is obtained by water influx coefficient B, based on the material balance equation of water drive gas reservoirs and the study of previous scholars. Thus a theoretical curve equation and a suppositional curve equation are derived and defined. The former one is pr(1-RgB)=1-Rg, which shows the relationship between the relative pressure pr and the degree of reserve recovery value Rg with different B. The latter one, pra=(1-ER)/(1-aEva)(where a=Sgr/Sgi), relates to the ratio of residual gas saturation and original gas saturation Sgr/Sgi, the ultimate volumetric sweep efficiency Eva and represents the relation between the relative abandonment pressure pra and the recovery ER. Finally, a set of charts is established by the two equations, by which we can set up a table to determine the variation range of the recovery with corresponding Sgr/Sgi value and Eva value when the aquifer is at different activity level.