bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Oil and Gas Decision-Making Taxonomy
Authors: Mackie S. I. , Welsh M. B. , Lee M. D. 
Published: December 2007

AbstractBusiness under-performance in the upstream oil and gas industry, and the failure of many decisions to return expected results, has led to a growing interest over the past few years in understanding the impacts of current decision-making tools and processes and their relationship with decision outcomes. Improving oil and gas decision-making is thus, increasingly, seen as reliant on an understanding of what types of decisions are involved, how they should be made in order to be optimal, and how they actually are made in the "real world".There has been significant work carried out within the discipline of cognitive psychology, observing how people actually make decisions. However, little is known as to whether these general observations apply to decision-making in the upstream oil and gas industry. Nor has there been work on how the results might be used to improve decision-making in the industry. This paper documents the development of a theoretical Oil and Gas Decision Making Taxonomy (OGDMT) that seeks to lay a "level playing field" decision space within which to judge the processes and tools of optimal decision-making as the first step in this research.The OGDMT builds on established ideas in the human decision-making literature, but is itself novel, and involves four different dimensions: level of investigation; task constraint; value function; and the information structure of the environment. It is concluded that decision scenarios at different places in the taxonomy will likely involve different decision-making tools, data and processes for the achievement of optimal decision-making.The results of this work can be applied, for example, to the question of whether decisions about reserves should be made using deterministic or probabilistic tools, data and processes.
Efficient Management of Production Losses to Increase Production
Authors: Tarmoom Ihab Othman , Khan Ayyaz Mahmood 
Published: December 2007

Abstract
Enhancing the field oil/ gas production, safely & without damaging the reservoir, in today's era is the top-most priority of each Operator. The fields' sustainability and aging facilities with integrity & HSE concerns, coupled with high market demand have presented real challenge to ADMA-OPCO. Accurate accounting of the field sustainable capacity/ development plans, strict compliance with good reservoir management guidelines/ practices, excellent planning of field activities (operations & maintenance, projects, rigs & barges, reservoir monitoring) and vigorous follow-up/ coordination at implementation stage have helped ADMA-OPCO to minimize the production losses. Initial gains resulting from short-term actions are 5 % & ADMA-OPCO is aiming at 15% or above improvement in production losses through medium to long term actions.
Efficient short, medium and long term production planning has taken key role in the management of hydrocarbon field operations. The market demands & increase trends, coupled with high oil prices have become so attractive for Operating Companies and Shareholders that every barrel of oil is essentially required to be lifted. Production targets today are set to the maximum available field potential, while ensuring facilities integrity & respecting reservoir guidelines for maximum sustained recovery.
The paper below will discuss the elements of production losses, analyze their relative impact on production capacity (referred to as "Effective Capacity") and recommend tools to efficiently manage the production losses with the objective to increase production. Although the discussion is more focused to large offshore operating oil fields, the principles can equally be applied to any onshore/offshore field.
Applicability of Horizontal Drilling Techniques in Iran: A Field Case Study in BiBi Hakimeh Field, Southwest Iran
Authors: Kalantari-Dahaghi AmirMasoud , Moghadasi Jamshid , Gholami Vida 
Published: December 2007

Abstract
Bibi hakimeh field, one of the biggest Iranian fields that has an important role in daily production of oil and gas, was discovered at 1961 by drilling well no. 1 and at 1964 the well started producing oil. Stratigraphic thickness of this field is 400 meter that increases in northern direction. And it has relation with Bangestan formation. Bibi hakimeh field is an oil saturated field which has a pressure of 2263 psi and a temperature of 147 °F at gas oil contact. Horizontal drilling techniques are applied for such "thin reservoir" which the vertical drilling depth is not enough.
This paper investigate the applicability of horizontal drilling technique in well # 74 Bibi hakimeh field that there was a need to use the horizontal drilling techniques, but this technique didn't have very good results in this field and the most horizontal wells that were drilled in this field had an equal or lower production than vertical wells. This method has advantages and disadvantages that are explained in this paper. The flow rate of vertical and horizontal wells is almost the same, but with respect to the geological structures and low reservoir thickness there was a necessity to drill horizontally. In this study the advantages and problems which horizontal drilling is dealing with are described. In addition some good data from wells that drilled horizontally in this field are available.
Primary Cementing in Permafrost Conditions—A Process
Authors: Radojevic Dean , Shafeyeva Yelena 
Published: December 2007

Abstract
By coupling dedication and commitment with the correct application of proven technology, primary cementing in permafrost conditions can produce long-lasting zonal isolation in the wellbore. Obtaining effective hydraulic sealing between cement and casing and cement to formation the operator may thus avoid unnecessary repairs, well shut-in and lost production.
Establishing good communication with the Tyumenniigiprogas Technical Instituee and operators well ahead of designing the job helps to identify all relevant factors influencing the potential outcome of the cementing operation and overall well turnout.
Ten wells were cemented in the Novo Zapolnarnaya field (Russian Arctic region) using the newly proposed blends; they all were successfully put on production without indication of crossflows. Slurry design considerations and operational placement suggestions are given to help reduce the chance of primary cementing failure over the producing lifecycle of the well.
Analysis of Rate Dependence in Transient Linear Flow in Tight Gas Wells
Authors: Ibrahim M. , Wattenbarger R. A. 
Published: December 2007

Abstract
Many tight gas wells (permeability less than 0.1 md) exhibit linear flow through their transient period. This transient period may last for years in some cases. It has been learned that this behavior differs in many ways from radial flow behavior. This paper reports another import difference between linear flow and radial flow - rate sensitivity.
It has been shown and accepted for years that real gas pseudo-pressure can be used to apply analytical solutions to transient radial flow. However, it has been noticed that analytical solutions can be in serious error when applied to transient linear flow. Specifically, the slope of the t departs from the analytical value as the flow rates or degree of drawdown become higher.
This paper demonstrates the rate/drawdown sensitivity of transient linear flow. Then a correction factor is presented which corrects the slope of the plot and improves the accuracy of kAc and OGIP, as calculated from production/pressure performance.
Multifactor Evaluation Technology for Casing Damaged Wells
Authors: Zhu Jun , Wang SuLing , Liu He , Wang Jingmei 
Published: December 2007

Abstract
Being a maturing field that has been developed for over 40 years, Daqing Oilfield has nearly 40 years of water flooding development history. One of the major problems that Daqing Oilfield is currently faced with is severe casing damage of both producers and injectors. Factors influencing casing damage are numerous, heightening difficulties in prediction and comprehensive analysis. In the past, casing damage mechanism research emphasizes on casing strength in respect of well drilling, fault and shale in respect of geology, and water injection pressure in respect of reservoir. Yet the accuracy for trouble shooting based on single factor analysis is quite low. To conduct casing damage mechanism research, the influence of multi-factors on casing damage should be considered comprehensively to draw a correct conclusion. Therefore, research on multi-factor evaluation technology and its application in casing damaged wells is implemented.
Three-layer feed forward neural network model is used to make the casing damage formation factors corresponding to the input vectors of the neural network. Factors causing casing damage such as water invasion in mudstone, pressure performance, geological features, casing performance, and stress field etc. are described as a series of real numbers between 0 and 1. More often than not, these factors are difficult to be described through mathematical methods, but a blurry value can be given by experts. Thus, a blurry vector for casing damage factor is composed of multi-factors, that is to say, the output of neural network is correspondent to the present working status of casings, which can be given by experts based on their experiences, and the output value is a description of the present working status of the casings. The given casing damage data is used as instructor signal to train the network, and following training, the network can perform the prediction of the working status of casings.
The New Hydraulic Fracture Design Method and Good Performance in a Deep and Naturally Fractured Volcanic Gas Reservoir in China
Authors: He Liu , Yongping Zhang 
Published: December 2007

Abstract
Due to the existence of multi-fracture and the extension in volcanic gas reservoirs, the success ratio of stimulation is very low as well as the stimulating scale. Based on the unique simulation model for fracturing development and growth during the stimulation, some important topics were studied: (1) the effect of the natural micro-fracture and stimulating parameters vs. the formation and extension of the stimulated fractures. (2) The magnitude of the affecting by different characters of the natural micro-fracture in the reservoir vs. the scale and success ratio of treatments. A new method was summarized to determine the operation indicators in real time on site. And this paper also introduced a series of main fracture controlling technique including: plug with rubber plug, plug with silty sand, displacement compensation at far end of the wellbore, etc. Two logging data from two wells in a large-scale stimulating process are presented in this paper, which proves the necessity and validity of the studying for the main fracture controlling technique in volcanic rocks. This method can also be used as a good reference for stimulation in the similar gas reservoirs.
Controlling Surge Due to Accidental Shutoff Fast Closing Value at Terminal Station of an Oil Pipeline
Authors: Wang W. , Gong J. 
Published: December 2007

Abstract
Changes of transportation materials, operating parameters or equipments of pump stations, will induce surge in oil transfer pipeline. And surge generated by accidental Shut-off fast closing valve could be more destructive, since the valve closure duration is limited, then the induced surge pressure would be much higher, so controlling surge of this kind is indispensable. Based on the characteristic method, this paper establishes a numerical calculation and simulates the pressure variation process, when fast closing valve at terminal station is accidentally shutted off in an product pipeline. Upon the upper result, further research combining the boundary condition of relief system is carried out, with the purpose of getting optimal surge control measures through relief system.
A Rigorous Composite-IPR Model for Multilateral Wells
Authors: Guo B. , Ling K. , Ghalambor A. 
Published: December 2007

AbstractUse of multilateral wells for oil and gas production has gained strong momentum in the past five years. However, most of the wells do not deliver hydrocarbon fluids at expected flow rates. One of the reasons is that the well planners over-estimate the productivity of wells using inaccurate methods for predicting composite IPRs of well laterals. A more accurate method for predicting composite IPR of multilateral wells is highly desirable. This paper fills the gap.Starting from terms that petroleum engineers are familiar with, a general mechanistic model was developed to combine the fluid flow from individual laterals. The model allows different IPRs of laterals and permits cross-flow between laterals. Pressure losses in both vertical and curvic hole-sections are rigorously considered. Oil and gas wells are treated differently. By combining the composite IPR model with Poettmann and Carpenter correlation, a computer simulator was developed for predicting multilateral well production rate. A case study with measured production rate indicated a 3.1%-error accuracy of the computer model, which is much better than other existing methods. This work provides petroleum engineers a reliable and user-friendly tool for designing and analyzing multilateral wells.
Quantification of Uncertainties for Drilling Induced Formation Damage
Authors: Ding Y. , Renard G. , Herzhaft B. 
Published: December 2007

Abstract
It has been widely recognized that formation damage due to drilling fluid has a huge impact on well productivities. The degree of formation damage can be studied using a numerical model. However, uncertainties in the prediction of productivity loss need to be investigated. To quantify these uncertainties, experimental designs combined with the Response Surface Methodology are used to assess the impact of uncertain parameters on formation damage. This approach allows to identify the most influential parameters on well productivity loss and to estimate the risks of formation damage. A good control of the most sensitive parameters can limit productivity loss. This approach provides key recommendations for the selection of drilling fluid to maximize well performance.
Applying Integrated Project Management Methodology to Hydrocarbon Portfolio Analysis and Optimization
Authors: Adekunle Sholarin Ebenezer 
Published: December 2007

Abstract
Aligning hydrocarbon investments with constantly shifting business goals and priorities continue to be a major challenge for E&P staff. In spite of the best efforts of international oil companies (IOC) to rebuild their in-house engineering and project management capability, an unacceptable number of oil field development initiatives continue to either fall short of, or simply miss their target completely. This is further exacerbated by insufficient supply of technical staff with experience in managing very large and complex projects. There is no end to the myriad of factors that can contribute to project failure and, as a result, petroleum industries have invested heavily to improve the predictability, producibility and quality of their output. While, techniques such as estimating, risk assessment, process management, deliverables management and project management improve project execution, they fail to address the more critical issue of scheduling and achieving satisfactory cost performances.
As the number of project opportunities grows, the corporate or financial planner is faced with an increasingly difficult task. Projects originally viewed or ranked as non-core or materially insignificant to the majors may have the potential to significantly impact the portfolio of an independent.
The main objective of this study is to explore the strategic significance of modern portfolio theory and its applicability to various oil and gas investments. In order to achieve this objective, the paper combines the strategic project management principles with hydrocarbon portfolio analysis. We draw on documentary sources (PMI's Guide to PMBOK, petroleum companies’ annual reports, status reports from existing hydrocarbon projects and so on). The paper demonstrates how modern risk techniques can facilitate the decision-making process in E&P operations.
A Novel Solution To Flow Profiling With An Improved Production Logging Tool In Short String Section Of Dual String Completions
Authors: Cig Koksal , Gok Ihsan 
Published: December 2007

Abstract
The new production logging tool string and interpretation technique were established in order to solve the surveillance limitations in the short string section of the dual completion wells. The logging program was initiated in Kuwait Sabriyah Field where there are two major producing formations: Mauddud Carbonate and Burgan Sandstone Formations. The wells were completed with dual production strings due to distinct fluid and reservoir properties in these formations.
Water injection was implemented in Mauddud Formation in late 2000 after a successful waterflood pilot program. The wells having water injection are mostly located in the short string section of the dual completions. The monitoring of the water breakthroughs and finding the bypassed oil became crucial for the field development. Understanding of the reservoir required logging these sections. The conventional wireline logging was regarded as a difficult and unsafe operation due to complicated nature of the production strings and the risk of wireline logging tool entangling. The earlier practice was to utilize the workover rig and to remove the two production strings before performing any wireline logging in the well. This operation was not only costly and time consuming but also pausing the production from Burgan Formation.
The new logging string and interpretation technique were developed to survey the short string section of the dual string completions without utilizing a rig. The logging operation consisted of conveying the production logging tool with a coiled tubing through the short string section of the dual completions. Flow profiles and water entries were confidently obtained in many wells with the new interpretation technique.
This paper presents the history of the short string logging operations in the North Kuwait Fields and highlights the improved coiled tubing conveyed logging tool string and the recent interpretation technique in order to overcome the problems due to completion restrictions.
Crude Stabilizer Using Localized Underpressure Generation
Authors: Valente Antonio , Granadeiro Adriano 
Published: December 2007

Abstract
The process of efficiently degassing and dewatering crude oil is a permanent concern in the industry from both, economical end environmental perspectives.
Oil and gas separators are utilized to achieve this purpose and are an integrant part of the surface separation equipment designed to handle the fluids produced from oil and gas wells and segregate it into oil/water and gas. They are installed either at the central processing plants or near the production wells.
The oil and gas separators consist normally in two families; the two stage-oil/gas separators and the three stage-water/oil/gas separators.
Their efficiency, translated by the quantity of gas separated from the crude oil is dependent upon
Physical chemical and electrochemical characteristics of the crude Process operating temperature Process operating pressure Equipment rate of throughput Size and configuration of the separator other factors
When the crude degassing process is not complete, then, at some point in the distribution circuit, for example at the refinery or while loading tankers, substantial amounts of associated gas will be released without control to the atmosphere, causing environmental damage (VOC emissions) a primary cause for the global warming, direct economical loss since part of the saleable product is lost and in some cases upset in the client's process due to high RVP.
Recognizing escalating concerns namely the potential increase in sea levels and flooding in coastal areas due to global warming, the actual market conditions of efficient utilization of hydrocarbon resources associated with zero flaring and venting targets are clearly sending the message that the development of complementary technologies targeting the enhancement of actual process conditions has become an obligation of all players involved.
Financing Strategies for the Procurement of Gas Projects in Developing Countries
Authors: Ellafi J. , Al-Thani F. , Merna A. 
Published: December 2007

Abstract
Numerous financial and contractual strategies are available to finance gas projects. In developing countries gas projects are financed and developed under different contractual strategies including; Production Sharing Contract, International Joint Venture Contracts or hybrid Project Finance strategies. These contractual strategies play a vital role in allocating risks involved in the procurement of gas projects. Gas projects are, in many cases able to access traditional forms of financing but the huge capital required to develop new gas projects to meet future gas demand may necessitate innovative approaches to be developed. This paper outlines the economic benefits to both public and private sectors for the adoption of Build-Own-Operate-Transfer (BOOT) strategies for the procurement of gas projects in developing countries (DCs). A comparison of the economic parameters of three strategies is also presented.
The Way the Oil Companies Tackle the Field Production Monitoring Problems in Russia
Authors: Ipatov A. I. , Kremenetskiy M. I. , Gulyaev D. N. 
Published: December 2007

Abstract
Field production monitoring problems in Russia are not related only to procedures; they also concern managerial issues. Usually there is no special department within an oil company that would interpret the well-test and production-logging results for their further use for production enhancement. "Sibneft" company is a rare exception where the results of all surveys are processed and interpreted in a specific department which constitutes a part of the company's structure and controls the well testing and production logging activities. The problems related to the well testing and production logging techniques are basically due to difficulties inherent to the production of residual reserves. Conventional well testing and PLT methods are poorly conclusive when applied in reservoirs with low permeabilities and poor producers with high watercuts. Sibneft implements therefore the welltest procedures that involve long swabbing stage followed by downhole well shut-in as well as long lasting welltests using memory remote control gauges including pressure gauges run into the well at the pump inlet. Stand-alone gauges such as pressure, temperature, spinners and watercut gauges are used for monitoring commingled production. Global technology for permeability adjustment based on logging, well testing, production logging and production data was worked out in Sibneft. Thus, 3D permeability cubes were generated for the most of the reservoirs and matched to the well-testing history; the relative distributions of flow properties being derived from log data. Problem of monitoring of the flow composition in the wells producing multiphase liquids and especially the horizontal wells is still poorly solved in Russia.