bluuebunny/crossref_metadata_2025_split huggingface dataset:
Methods for Delineation of Fractured Oil Bearing Conglomerate Reservoir
Authors: Liang Xing Ru , Lu Chuan Bing , Du Xin Jiang , Yuan Ke Feng 
Published: December 2007

Summary
A few conglomerate oil bearing reservoirs were discovered at the northwest end of Langgu sub-depression, a local lacustrine sub-depression of the famous North China's Bohaiwan Basin. Among them, Tong 43 block is complicated in pore spaces, according to core analysis and FMI log pictures, both matrix pores and fractures occurred in this reservoir. 5 wells have been drilled so far. The oil productivity and the degree of fracturing of the reservoir of each well are of great variation. Therefore, the nature of fractures and their distribution must be clearly understood prior to production drilling program.
Two types of analysis have been applied in this study: 1) geologic analysis on genetic conditions of fractures, including studies of structural features, sedimentary facies and deformation of faulting; 2) seismic techniques, to discover the relationship between fractures and anomaly of seismic attributes, and azimuthal seismic anisotropy, thus outlining the distribution of fractures based on seismic data processing.
Through this study, three sets of fracture detecting techniques have been effectively established: 1) techniques based on genetic analysis; 2) techniques based on seismic attributes analysis, where analysis on discrepancy between different post stack attributes has been applied; and 3) pre-stack seismic techniques based on amplitude and frequency analysis on 3D seismic volume processed with varied azimuthal gathers. In this analysis, azimuthal seismic anisotropy analysis on P wave seismic data played an important part in fracture interpretation about orientation and intensity. The results of the fracture detection of each technique were reevaluated by comparing with well data and geologic conditions. The properties of oil bearing Tong 43 conglomerate bodies were evaluated in greater detail afterwards, and rich oil bearing zones were located. This study not only provides guidance for production drilling program of Tong 43 block, but can be a reference for similar reservoir delineation as well.
A New Method of In-Depth Profile Modification for High-Temperature and High-Salinity Reservoir
Authors: Tang Xiaofen , Liu Yuzhang , Qin He , Cai Lei , Jiang Ruyi 
Published: December 2007

Abstract
Reservoirs in Tarim Basin, China west, were geologically formed in marine environment with high temperature (over 140) and high salinity (up to 25% TDS and 1% Ca2+ + Mg2+). After 10 years of development by water flooding, unwanted water production become a big problem. This is caused by uneven water sweep due to severe reservoir heterogeneities. Unfortunately, there are no in-depth profile modification agents that can stand such harsh reservoir conditions.
To address the problem, a novel process is developed which takes advantage of the multi-valence cations concentrated in both the formation and injection water and injects a compounded silicate to react with the cations to form gel, so the method is cost effective. Bulk gel or disperse gel can be formed depending on the proportion and concentration of the silicate and multi-valence cations in the water. Beaker test shows that the gel has desired properties of HT/H Salinity resistance and long-term stability. Core flood tests verify that, by slug injection, the process can gradually build long lasting residue resistance factor (RRF) for water flow in high permeability streaks indicating a "layering" or "coating" mechanism. To investigate the possibilities of gel adherence to tubing, slim tubing physical simulation is also performed.
Formation Damage Mitigation in High Pressure High Temperature Gas Field
Authors: Hamid Pauziyah Abdul , Yaakub Mohd Azriyuddin , Ganesan Nadeson , Kasim Selamat 
Published: December 2007

Abstract
During a workover campaign in one of the high pressure gas field offshore Peninsular Malaysia, several wells have been identified as potential to provide additional gas production. One well in particular, was suspected to have severe formation impairment in which the project team believed could be removed through the use of demulsifying wash agent and mineral complex dissolver.
During the drilling campaign of the well, production zone was drilled with 14 ppg OBM. After perforating the well, the brine system used (11.6 ppg CaCl2) was unable to contain the pressure. It was then decided to revert to OBM since higher brine weight was not sufficient to secure the well. The well was then completed with the same. However the well was producing below performance and was not doing any better with acidisation.
Following that, a laboratory assessment was conducted to evaluate the extent of the damage and to investigate the performance of a demulsifying wash agent and minerals complex dissolver in mitigating the formation impairment.
This paper described the laboratory assessment and field implementation of the chemicals in mitigating formation impairment that occurred in the reservoir. The results from laboratory assessment on compatibility analyses, corrosion test and core flow test were presented and discussed. In addition, the results from field implementation were also presented and discussed.
Characterizing Permeability for the Fractured Basement Reservoirs
Authors: Li Bingjian , Guttormsen Joel , Hoi Tran V. , Duc Nguyen V. 
Published: December 2007

Abstract
Permeability is one of the major controls for production in fractured basement. It is critical to be able to identify and characterize permeable zones in the basement reservoirs not only for evaluating well producing potential but also for designing perforation, well completion and injection. Even though geoscientists and reservoir engineers have made considerable effort over the years to better characterize the permeability profile in fractured basement, it is still very challenging to achieve this objective.
This paper presents a newly developed approach aimed at better understanding the permeability profile. The technique was developed based on case studies from wells in two different basement fields located offshore in the south of Vietnam. Traditionally, fractures have been characterized using core and borehole image data. In this study, borehole image data were integrated with other open-hole logs to derive a permeability curve. The result was calibrated with core data and then validated with dynamic data i.e. production log data, well testing data, mud losses, gas shows. As demonstrated in the case studies, it is believed that the permeability in the basement could be reasonably evaluated using this method. However, in a zone where fractures are cemented or partially cemented with conductive minerals, the log-derived permeability needs to be calibrated with the degree of cementation.
Thermal Desorption of Oil from Oil-Based Drilling Fluids Cuttings: Processes and Technologies
Authors: Stephenson Ralph L. , Seaton Simon , McCharen Robert , Hernandez Edgardo , Pair R. Benson 
Published: December 2007

Proposal
This paper presents the results of a study of processes and technologies for the thermal desorption of oil from oil-based drilling fluids cuttings for both onshore and offshore applications. A field investigation of available technologies designed to separate oil from oil-based drilling fluids cuttings by thermal desorption was conducted. In addition, some technologies that perform separation by physical-chemical means were also investigated; however, all commercial processes presently available use thermal desorption.
The mechanisms of desorption of oil from cuttings were investigated. Process parameters and theoretical concepts for thermal desorption by distillation were developed using proprietary computer simulation programs for the distillation of hydrocarbons. Theoretically ideal temperatures for the process were calculated for various conditions and for various oils. The impact of moisture and oil content on the heat balance was calculated. The recoverability of the oil under various conditions was investigated.
Nineteen companies were contacted for information on their desorption technology. Twelve company sites were visited to determine the developmental stage of their technology and to determine how well the technology functioned in the field. The technologies were evaluated for air emissions, liquid emissions, safety, oil content of processed material, space requirements, utility and chemical requirements, and other operating and design factors. Applicability of the technologies for offshore use was evaluated. Safety and environmental issues for each technology and the recycling of oil are also addressed in this paper, along with future work needs in this area.
Screening Methodology for Downhole Sand Control Selection
Authors: Farrow Chris , Munro David , McCarthy Thomas 
Published: December 2007

Abstract
The Sand Management Strategy for existing North West Shelf (NWS) fields involves reactive downhole sand control in the event sand is produced above acceptable limits. Sand face completions for new wells consider well and system risks over the life of the development.
A screening methodology has been developed to evaluate and rank the available sand control techniques for NWS conditions. Published criteria are used in a systematic manner, allowing a consistent, balanced and transparent view of benefits and risks across the different ‘system’ aspects.
The methodology incorporates a combination of a flowchart and sand control matrix, where each selection criterion is evaluated according to a likelihood × consequence ranking. In this way all relevant information and its relative importance are included in the decision making process.
This paper describes the methodology and its application for conceptual design across a number of NWS high rate gas well case studies. These range from existing, near-vertical platform wells to new, horizontal subsea wells.
A Plastic Pre-Coated Gravel For Controlling Formation Sand (February 1980)
Authors: Underdown David R. , Day Jon C. , Sparlin Derry D. 
Published: December 2007

Abstract
Results of field tests and laboratory evaluation have shown that a plastic pre-coated gravel system is a successful method of sand control for both non-thermal and thermal wells. Significant improvements in this process have been made which provide higher compressive strengths, increased quality of coating, greater chemical and thermal stability and higher permeability of the consolidated gravel. These results have been obtained by using higher quality gravel, an improved coating process and improved placement techniques.
Full scale pumping tests and actual field results indicate that this system provides a consolidated gravel pack capable of controlling sand production without impairing fluid production. The use of this type of material even prior to the improvements has provided good sand control in both injection and production wells in the offshore Gulf Coast region for over a year. Field results in the San Joaquin Valley, California have demonstrated that it is also well suited for sand control in moderate temperature thermal wells. Wells using both steam drive and huff-and-puff methods of stimulation which have employed this improved plastic coated gravel have increased production and virtually eliminated bailing of sand.
Methane Pressure Cycling Process with Horizontal Wells for Thin Heavy Oil Reservoirs
Authors: Dong Mingzhe , Huang Sam , Hutchence Keith 
Published: December 2007

Abstract
The methane pressure cycling process is an enhanced oil recovery scheme intended for application in some heavy oil reservoirs either after termination of primary, or waterflood, production. The essence of the process is the restoration of the solution gas drive mechanism. The restoration is accomplished by re-injecting an appropriate amount of solution gas (mainly methane) and then re-pressuring the gas back into solution by injecting water until about original reservoir pressure is reached. This, aside from the replacement of produced oil by water, re-creates the primary production conditions. This novel recovery technique is being developed to target the considerable portion of heavy oil resource located in thin reservoirs. Primary and secondary methods have managed to recover at best 10% of the initial oil-in-place. Heat losses to overburden and underburden or bottomwater zones make thermal methods unsuitable for thin reservoirs.
Coreflood tests in 30.5 cm (length) H 5.0 cm (diameter) sandpacks were carried out for oils with a range of dead oil viscosities from 1,700 to 5,400 mPa.s. The results showed that the pressure cycling process could create a favorable condition for recharged gas to contact the remaining oil in reservoirs. This restores the situation whereby substantial amounts of gas are in solution for further "primary" production. The effects on the efficiency of the methane pressure cycling process of cycle termination strategy, oil viscosity, and mobile water saturation were investigated. Simulations were conducted to investigate the methane pressure cycling process in three heavy oil reservoirs in Saskatchewan, Canada. The effects on the process of infill wells, oil viscosity, gas injection rate, and the presence of wormholes in reservoirs were studied.
Using Intelligent Well Technology to Define Reservoir Characterization and Reduce Uncertainty
Authors: Paino Wan-Faisal , Tengah Noorilmee H , Woodward Myles I. , Snaith Nigel , Salleh Hadizah , Browne Mark 
Published: December 2007

Abstract
A three-hole appraisal campaign was conducted in 2002 with objectives to reduce the in-place volumetric uncertainties, reservoir connectivity and deliverability uncertainties of the Bugan oil/gas field, offshore Brunei. Bugan-6 and Bugan-6st1 were drilled to address volumetric uncertainties. Bugan-7 was drilled and completed from the nearby Iron Duke facility. The well was an early development/appraisal well in four separate oil rims. A three zone intelligent completion was installed with the specific objective of assessing compartmentalization and deliverability uncertainties before full field development.
The intelligent well components consisted of three surface controlled internal control valves (ICVs), a distributed temperature sensor fibre (DTS) and six downhole pressure gauges (PDHG).
The ICVs has enabled each of the zones to be tested individually without incurring deferment or intervention costs. In addition to acquiring productivity data on each of the individual zones, the ICVs have enabled downhole shut-ins to be performed and corresponding permeability data and skin data to be obtained.
After six months of production, an increase in GOR was observed. The DTS data showed gas breakthrough has occurred in a thin sand in the lower producing zone. Early identification of this high permeability sand has enabled refinement of the simulation model and adjustment of future well designs to minimize impact.
Accurate zonal production and pressure data has allowed a preliminary material balance to establish the minimum connected volume to the well. This information has discounted the highly compartmentalized reservoir scenario.
Installation of the intelligent completion has enabled a significantly better reservoir model to be developed with a reduction in the uncertainty ranges. This will enable optimization of future wells in the field and significantly increase the value of the field.
The Use of Drilling Cutting in Measuring Permeability, Can This Be Done?
Authors: Talabani Soran , Thamir Falah 
Published: December 2007

Abstract
The current available equipment used in the laboratory to measure core sample permeability is limited. Special core size is needed for the equipment, core faces are always damaged while cutting, and samples cannot be oriented to measure vector permeability.
The right way to measure absolute permeability is by using a non-damaged core sample by chipping it off from the rock. This is difficult though.
A new design is particularly made so that a piece of cutting can be used to measure permeability. This can accommodate for different drilling cutting size, minimum size is needed though.
The benefits of using cutting samples are; measurement of vector permeability, cutting faces are not damaged hence, more realistic measurement, and this measurement is made instantly in the field.
A Practical Approach to Solids Control Through Economic Evaluation of Mechanical Equipment
Authors: Conyers J. C. 
Published: December 2007

Abstract
A good solids control program is essential in order to attain the goal of an optimized drilling program. Proper application and utilization of mechanical solids removal equipment enables the driller to maintain the desired drilling fluid properties which in turn makes it possible for the drilling operation to be carried out in an efficient and economical manner.
Drilled solids have a direct and pronounced effect on the drilling fluid. Since the drilling fluid is itself so closely related to a wide range of factors which determine both daily and total drilling costs, it is obvious that there exists a strong relationship between the control of drilled solids and the control of drilling costs.
This paper will present methods to calculate the mechanical efficiency of solids control equipment on site during drilling operations and will demonstrate from case histories a method of determining the economic justification for the use of mechanical equipment.
Data presented in this paper is based on information gained in the field evaluation of various types of solids control equipment, including sophisticated fluids processing systems, under a wide variety of weather, geographic and geologic conditions.
Underwater Communication, Navigation and Positioning in the Waters of Tomorrow
Authors: Elson Scott , Mann Jim , Stuart Ross 
Published: December 2007

Abstract
Today the offshore industry requires more from its navigation and positioning technology: more accuracy, more integrity, more range or depth and more data. With the advent of super fast wireless communications in the home and office, it is often the case that the physical limitations of the environment in which we work underwater is less well understood, especially when you combine the demands for "More" with those of "Less" from the purse holders. This paper will deliver an insight into a technology that is being used by ROV, AUV, DP Vessels, Ships and the Subsea Production Hardware to, not only position and navigate underwater, but also to communicate, without the use of cables It will include details of recent implementations of these technologies including the "Underwater GPS" and "Wireless Control System". Applications and experience with 21st Century Acoustic Technology will set the audience thinking of the other possibilities open to them.
Subsea Multiphase Boosting - Maturing technology Applied for Santos Ltd's Mutineer and Exeter field
Authors: Grimstad Haakon J. 
Published: December 2007

Abstract
The paper presents the state of art in subsea multiphase boosting. This includes the subsea pump, subsea integration, power and control system, umbilical, and intervention.
Further, the typical applications and characteristics for subsea multiphase boosting systems will be addressed. The benefits to the users are normally related to reduced investments and even more important, increased and/or accelerated oil production. There are also several examples of subsea multiphase pumps as production enabling equipment. Typical reference projects and field experience will also be presented.
Although multiphase pumps in most cases are used as independent systems there may be a significant potential in combining this solution with other artificial lift technologies. They may be used in combination with gas lift or downhole pumps to offer integrated systems with premium reliability and economics.
The second part of the presentation will be related specifically to the subsea multiphase pump system recently selected for Santos LTd's Mutineer and Exeter field offshore NW Australia. The overall subsea system architecture will be presented with particular focus on the subsea multiphase pump system. Considerations, advantages and expectations to this solution as seen by the operator, will be addressed.
Modifying a Pipeline Corrosion Management Strategy to Changing Conditions
Authors: Russ Paul R , Rainsford Christopher 
Published: December 2007

Abstract
Internal corrosion in pipelines is an industry-wide problem. Papers have been written describing inspection tools and smart pig findings, but few focus on how to modify a corrosion management program to halt corrosion once an affected pipeline is identified. This paper discusses actual field data obtained from Esso Australia's main oil pipeline, and presents the corrosion management changes that were necessary to control further wall loss.
This paper demonstrates that a broad, disciplined approach to monitoring and sampling is required to control pipeline corrosion as conditions change. Differentiation between export and inter-platform pipelines is made and the different types of corrosion inhibitor to use in these lines are considered. The effect of platform upsets and ways to mitigate the impacts of additional water to pipeline are discussed, as is the development of a comprehensive and meaningful sampling program.
The threat of microbiological induced corrosion (MIC) to pipeline life and mitigation tactics that are being employed is also presented. Comparisons between old and new inspection and monitoring results will be given to demonstrate the benefits of adopting the new corrosion management program.
To effectively prolong the life of an old pipeline network operating in a mature operation, proactive changes to a pipeline corrosion management strategy incorporating field analysis and monitoring are required.
Development Techniques for Abnormal High-Pressure Gas Fields and Condensate Gas Fields in Tarim Basin
Authors: Song Wenjie , Jiang Tongwen , Wang Zhenbiao , Li Ruyong , Feng Jilei , Zhu Zhongqian 
Published: December 2007

Abstract
Tarim Basin is the most hydrocarbon-abundant onshore basin in China. It occupies an important position in "West-to-East Gas Transportation" project. The major force gas fields are of large scale, abnormal high prossure and high productivity of a single well. The condensate gas fields are usually of high formation pressure, high condensate oil content and high pressure of dew point. Through deepening study on the development mechanism and development technologies of the gas fields and condensate gas fields, a series of development technologies in the super-deep and high-pressure gas fields and condensate gas fields in Tarim Basin have come into being in the development practice. The technologies not only have helped to build up Yaha Condensate Gas Field with the largest condensate oil productivity in China, but also have been extensively applied in the early-stage development eveluation of several gas fields in "West-to-East Gas Transportation" project and the comprehensive adjustment of Kekeya Condensate Gas Field. A new model has been created to develop super-deep and high-pressure gas fields and condensate gas fields.