bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Hybrid Artificial Intelligence Method for the Optimization of Integrated Gas Production System
Authors: Park Hui-June , Lim Jong-Se , Kang Joo M. , Roh Jeongyong , Min Bae-Hyun 
Published: December 2007

AbstractThe optimization of gas production system has been largely based on a nodal analysis approach of individual wells. This approach limits the overall benefit of a field study because it ignores complicated flow interactions among wells during the optimization process, often resulting suboptimal operations. A major impediment in the formal optimization of large petroleum producing fields is the excessive computation time during optimizing processes. The conventional deterministic algorithm can not take into consideration the uncertainties regarding nonlinear and complex systems.This paper proposes a new hybrid artificial intelligence approach for field-wide optimization of integrated production system including gas reservoir, well flow, and surface production network. An advanced polynomial neural network (PNN) with layer over-passing structure has been developed to replace a relatively time consuming reservoir simulator through robust and systematic search algorithm. The networks are subject to some form of training based on a representative sample of simulations that can be used as a re-useable knowledge base of information for addressing many different management questions.For an optimal design of gas production systems, this study uses an integrated simulation model implemented by coupling a PNN with surface production network and optimization scheme based on fuzzy nonlinear programming approach to accommodate uncertainties by combining the fuzzy λ-formulation with a co-evolutionary genetic algorithm.The proposed approach significantly reduces computational effort for optimization of the development scheme within reasonable accuracy. The hybrid optimization method can find a globally compromise solution and offer a new alternative with significant improvement over the existing conventional techniques. This technique provides optimum production rates of each well of the entire production system to deliver the target rates over the period of the gas contract requirements. This system has been validated by synthetic case study offering an important element for management of gas production strategies and field development.
Adding Value to Oil and Gas Fields through Systematic Full Field Reviews
Authors: Balnaves C. , Bangkong S. , Herweijer J. , Irrgang H. R. , Khurana A. K. , Lammerink W. , Palmer I. D. 
Published: December 2007

Abstract
A Full Field Review (FFR) is a comprehensive multi-disciplinary integrated re-evaluation of all basic reservoir characterisation data, dynamic reservoir and well performance data as well as relevant surface facilities pertaining to an oil or gas field to maximise knowledge and understanding of the field. The basic purpose of FFRs is to formulate and maintain evergreen initial and ongoing development plans to maximise full lifecycle value of the field. FFRs are a key component of integrated reservoir management.
Pre development FFRs are standard industry practice, their value is well understood and are prerequisites to development approval by regulatory authorities and budget sanction by corporations. Brownfield FFRs on the other hand are conducted on an ad-hoc basis.
We believe that systematic, timely and well focused brownfield FFRs add significant value by identifying potential production and reserves optimisation opportunities in and around brown fields. Most value is added by questioning prevailing assumptions, seeking and explaining anomalies, finding creative solutions and looking for opportunities to add value through application of new technologies. The importance of mutually optimising the reservoir, wells and surface facilities cannot be overemphasised.
Alternative static and dynamic realisations of the reservoirs are tested under different operating strategies via reservoir models to search for additional development opportunities, not only within the field under study but also in its geographic proximity so as to utilise and/or build upon the existing surface facilities and infrastructure. FFRs also help in justifying reserves reclassification of probable and possible reserves into higher categories. Alternatively they can identify appraisal and data requirements to justify such reserves reclassification.
The Malaysian regulatory regime administered by the Petroleum Management Unit (PMU) of Petronas formally requires its production sharing contractors to conduct periodic brownfield FFRs. This paper reports the results of a 2005 PMU sponsored benchmarking study of international industry and regulators' Full Field Review best practices. Results of implementing FFR outcomes in three fields together with predictions of four further FFRs completed to date on Malaysian fields are also provided.
A Systematic Approach to Incorporate Capillary Pressure-Saturation Data into Reservoir Simulation
Authors: Wang Y. , Bandal M. , Moreno J. , Sakdilah M. Z. 
Published: December 2007

Abstract
The Capillary-saturation function plays an important role in describing fluid distribution and modeling flow in reservoir simulation. In our full field review, a systematic procedure was developed to establish a capillary pressure-saturation correlation honoring various sources of information such as laboratory measurements and well log data in the following steps:
Laboratory capillary pressure and saturation data of a variety of measuring methods were processed to represent capillary pressure versus saturation at reservoir conditions. A method was established to determine the practical transition zone height and irreducible water saturation. A reliable correlation between the irreducible water saturation and rock quality index was derived, and the normalized saturation was calculated. Capillary pressure was normalized using the J function, and an optimal correlation of the J function and normalized saturation was established.
Following these steps, a normalized capillary pressure-saturation function including values for rock-quality dependent irreducible water saturation and end-point capillary pressure was established for simulation use. During upscaling of the fine scale geological model to the relatively coarse flow simulation model, one of the key goals is to preserve the hydrocarbon volumes from the fine scale model. Several approaches were tested. Advantages and disadvantages of each method were investigated and an optimum method was chosen for the study that was robust and yielded satisfactory results.
This paper describes our approach and addresses the following important practical issues:
determination of irreducible water saturation and transition zone height, normalization of capillary pressure and saturation, and preservation of hydrocarbon volumes during upscaling.
The optimal solutions to these issues are discussed. The application of the method to our full field study is presented.
Rapid Pressure Support for Champion SE Reservoirs by Multi-Layer Fractured Water Injection
Authors: Sommerauer G. , Zerbst C. 
Published: December 2007

Abstract
The Champion field is a large oil field offshore Negara Brunei Darussalam. This paper discusses the-for us-novel application of multi-layer fractured water injection into three shallow reservoirs in the Champion Southeast field (CPSE). The project is part of a larger secondary recovery implementation scheme and future efforts to increase economic oil production and ultimate recovery in the whole Champion field.
The main boundary condition for the rapid water injection project is the use of existing infrastructure with the exception of three new water pipelines and nine new wells. This paper describes the following:
Reservoir setting and production history. Water injection philosophy. Design considerations for fractured water injection including: ○ Pressure requirement to design for fractured water injection. ○ Simulation of fracture growth and containment and resulting conclusions. Design considerations for the multi-layer fractured water injector wells including: ○ Selected Drilling Aspects (well trajectory, drill-in fluid, formation evaluation, casing scheme). ○ Completion Design Considerations (clean-out, perforating, sand control, selectivity, "smartness", other). ○ Material selection.
One of the main conclusions is that fracture growth and containment is not a major issue in soft, high-permeable formations. The main challenge is in drilling the sometimes-demanding well trajectories and running the ("smart") completions in these wells with small tolerances.
Water Control and Fracturing: A Reality
Authors: Mahajan M. , Rauf N. , Gilmore T. , Maylana A. 
Published: December 2007

Abstract
Water production in mature fields is a common situation. In many mature areas, every barrel of oil is being produced with six to ten barrels of water. The production of water results in increased operating expenses along with other water related well problems like scale, fines migration, sand face failure, water loading in wellbores etc.
The goal of any hydraulic fracturing treatment is to increase the production potential of the well. This is achieved by parting the formation rock under pressure and leaving it "propped" open to create more conductive path between the reservoir and wellbore. This technique has become a common and routine method of stimulating oil or gas wells.
Many operators do not associate the stimulation and water control objectives in the same treatment. In fact, it is usually the opposite; the candidate is rejected for a hydraulic fracturing stimulation treatment because of the fear of increasing the water rate. This should not be the case for a few reasons. The first, a mature well will produce water with or without the hydraulic fracture treatment. The second, the emergence of a new stimulation technique over recent years that combines water control technology as part of the hydraulic fracturing treatment, offering the potential for reduced post frac water cut with the gains in productivity that a hydraulic fracturing treatment can offer.
The conformance fracturing technology opens the possibility to stimulate high water cut wells while controlling the water simultaneously. This is achieved by using specially designed relative permeability modifiers (RPMs). By placing the RPMs in the fracturing fluids, resistance to water flow will occur in the filtrate-invaded area opposite the fracture faces. The conformance fracturing treatment generally results in a net increase of oil flow with reduction in the water cut.
This paper will review the evolution and progresses made in the field of conformance engineering with special focus to their applications in conjunction with fracturing treatments. It will describe the successful application of conformance fracturing technology in a mature field in South Sumatra, Indonesia. The placement method, RPM technology and the field case histories of successful treatments shall be discussed in order to substantiate the technology.
Research on Remaining Oil Distribution and Further Development Methods for Different Kinds of Oil Layers in Daqing Oilfield at High Water-Cut Stage
Authors: Chengfang Shi , Qinglong Du , Lihong Zhu , Shanyan Zhang , Lei Zhang , Xiaowei Jian 
Published: December 2007

Abstract
Daqing oilfield is multi-layered sandstone oilfield with serious heterogeneity1. After more than 40 years flooding, the oilfield has entered the high water-cut stage when the water flooding and polymer flooding are coexisting. After multi infill drilling and multi adjustments, different kinds of oil layers have been swept with certain degree, and the remaining oil distributes highly scattered2,3. Three types of oil reservoirs can be divided according to their properties and their grown conditions. Due to the difference in reservoir properties and development strategy, the potential and problems exited for various oil reservoirs are not the same. In Class I oil reservoir, the contradiction is mainly caused by the coexistence of remaining oil, which is resulted by heterogeneity in oil layers, and inefficient water circulation; In Class II oil reservoir, the main contradiction is caused by the coexistence of water flooding and polymer flooding both in vertical and areal; In Class III oil reservoir, two main contradictions are incomplete production-injection structure caused by discontinuous sand body development in areal and interlayer interference caused by too many oil layers in vertical. In view of the main contradictions and problems in different oil reservoirs, and with the consideration of current production technology, the relevant further development measures for different oil reservoirs are determined, and the field application results are fairly good. New methods and techniques to improve the swept volume and displacement efficiency in different oil reservoirs at super high water cut stage are also discussed in this paper.
A High Success Rate Acid Stimulation Campaign—A Case History
Authors: Al-Araimi N. , Jin L. 
Published: December 2007

Abstract
A successful acid stimulation campaign was conducted in 2004 in Brunei Shell Petroleum (BSP). This paper discusses what have been done differently, best practices, and learning.
What is different in this campaign from previous ones? Detailed design
Detailed well-by-well review for first round candidate selection. Fundamental data collection (well data, pressure, formation fluids - water and oil, mineralogy data and lab tests…). Data management system allowing for quick access to well production history data. A design tool (Stim2001) for detailed candidate selection, damage diagnosis, fluid system selection, and job design. QA/QC and compatibility tests aiming to obtain high success rate.
In Brunei Shell, a self-raising rig (BIMA) with a coil-tubing unit on board is used to overcome the limitations due to weather.
A combined pumping procedure (coiled tubing and bull-heading) was implemented to best-fit individual well condition.
Close cooperation among different parties (Well services, Subsurface technology teams, Operation services, and Service providers, etc.)
6000 bpdoe of initial gain was achieved by this campaign in Brunei with high success rate (no failure on single well was recorded).
Confidence level of acid stimulation in Shell Asia Pacific region has been elevated through this stimulation campaign. Lessons learnt and best practices established will be passed to future campaigns. We would like share our belief that acidization is still a good means for stimulating well productivity, but it has to be carried our properly.
Vertically Fractured Well Performance in Rectangular Drainage Area
Authors: Sabaev V. V. , Wolcott D. S. , Mach J. M. , Antipina D. V. , Haidar A. M. , Sviyazova O. O. 
Published: December 2007

Abstract
This paper presents two new models to define the dimensionless productivity index of finite conductivity fractured well either for pseudo-steady state or steady state conditions in the rectangular shape reservoir.
Maximum dimensionless productivity index (JD) of a fractured well in a square drainage is 6/π at pseudo-steady state, and 4/π steady state. The same well in a rectangular drainage can have larger JD with the same area and dimensionless proppant number (Nprop).
Since rectangular geometry provides much larger JD, it seams reasonable to consider this geometry for field development. For a given set of reservoir conditions there is an optimum rectangular geometry aspect ratio (rectangle length width ratio), which when fractured properly, will yield the maximum possible JD under pseudo steady state. Optimizing the aspect ratio impacts the well spacing, which has major significance for field development planning or infill evaluation. The purpose of this work is to provide performance type curves for a fractured well in rectangular drainage area and provide a methodology to determine the optimum aspect ratio for a given set of reservoir conditions.
A Case Study of a Successful Chemical Treatment to Mitigate Asphaltene Precipitation and Deposition in Light Crude Oil Field
Authors: Sanada A. , Miyagawa Y. 
Published: December 2007

Abstract
This paper describes the results of an investigative case study to identify the causes of productivity decline in an oil well and a successful chemical treatment to restore productivity.
A well in a Japanese oil field has suffered from a significant productivity decline from the beginning of commercial production. Pressure build up tests have shown the presence of formation damage becoming larger as production goes. Then we considered the possibility of asphaltene deposition, which has been observed in most of the surface facilities, in the near wellbore formation restricting flow capacity around the well.
A multidisciplinary team was organized, with field operation engineers and researchers from the R&D center, to investigate the asphaltene behavior in the formation and to find the effective way of chemical treatment as asphaltene-control measures.
Laboratory analyses using bottom-hole fluid samples have built the onset pressure curve of asphaltene precipitation, which indicated the asphaltene deposition in the near wellbore region under the production conditions.1
Then the intensive laboratory tests have been carried out to evaluate some commercial additives in terms of their efficiency as an asphaltene inhibitor under the formation conditions and to find the most effective chemical to resolve precipitated asphaltene.
Based on laboratory analyses and tests, a complete chemical treatment program consisting of injection of Xylene into the formation with a three feet treatment radius and squeezing of an asphaltene inhibitor around the well has been designed and applied to the well.
This chemical treatment resulted in a significant improvement in the productivity index which is almost ten times larger comparing as before.
A Constraint Management Based Planning Approach to Delivering Exploration, Development and Production Work Programmes
Authors: MacDougall I. , Saman K. 
Published: December 2007

Abstract
Stuart Petroleum is an emerging independent oil and gas company, operating an exploration, development and production work programme in the Cooper Basin in central Australia. The company's philosophy is to operate as a virtual organization, outsourcing many aspects of its programme in order to leverage the capability of local and international service and technology providers to gain competitive advantage. With an approach such as this, driven by a very small central leadership team, an effective planning capability underpinning effective execution becomes a critical core competency.
Even in a small company such as Stuart, the exploration, development and production programme contains in excess of 5000 key items in any one year, including both office and field activities. Stuart Petroleum uses a state of the art MP-ReMS™ (Multi-Project Resource Management System) planning platform, which dynamically models the oil and gas exploration development programme across the enterprise, based on key corporate objectives.
This capability has yielded significant benefit in optimising resource and materials utilisation and has facilitated substantial cost reductions. Stuart Petroleum has successfully linked its planning strategies directly to its corporate objectives hence connecting the work programme directly to the outcomes achieved for its shareholders. The planning platform models the deployment of critical resources and also tracks milestones in the undertaking of each event, underscoring the priorities of the business.
A Constraint Management approach is employed to accelerate drilling and production hookup of a ranked seriatum of oil and gas prospects with minimal resource and material wastage. This approach offers far greater flexibility compared to traditional time based scheduling methods such as critical path analysis.
The system developed incorporates a "what if" Scenario Analysis capability that allows the leadership team to explore strategic options and their impact on the "current best plan" and corporate objectives.
This paper illustrates the approach taken, highlighting some of the challenges faced and outcomes achieved when managing a large number of concurrent activities competing for finite resources, through effective application of a constraint management approach.
Kutubu: A Rethink
Authors: Williams N. , Lund D. 
Published: December 2007

Abstract
Kutubu is Papua New Guinea's largest oil field. It came on line in 1992 and achieved peak rates of over 130,000 stb/d in 1993 before decline commenced in 1994. Capacity was still 45,000 stb/d at the beginning of 1998 but Kutubu production rates declined rapidly and half the field capacity was lost during 1998 to 2000. It was beginning to look in 2001 as if the field would be completely shut in within a few more years.
Kutubu was originally developed on the basis of a dynamic aquifer (or tilted contact) theory that was used to explain the apparent lack of oil along the northwest side of the field.
A field review conducted by the operator identified an alternate theory of compartmentalisation to explain the non-uniform oil column. As the alternate hypothesis was as good at explaining the early data and better at explaining some of the more recent performance, it was decided to abandon the original concept and test the new theory by drilling in areas the original concept would have predicted to be unprospective. Drilling results were conclusive-there was oil and little or no water in the centre of the field. Consequently, the compartmentalisation theory opened up a series of opportunities in areas that were previously considered unprospective due to the tilted contact concept, and a followup development campaign, along with other projects, has for four straight years completely halted the production decline. The field now appears to have a considerable remaining life of up to 2 decades.
Material Balance Analysis in Complex Mature Reservoirs–Experience in Samarang Field, Malaysia
Authors: Bui T. , Bandal M. , Hutamin N. , Gajraj A. 
Published: December 2007

Abstract
In this paper we present the results of a material balance study for a mature field in East Malaysia. The field consists of several stacked sands and is highly faulted, resulting in a complex system of several compartmentalized reservoirs. The drive mechanisms of these reservoirs range from strong gas cap drive to strong water influx or combinations of these. Fourteen material balance models were built and the results analyzed. This study shows that proper integration of all pressure, production and geological data is critical in defining reservoir compartmentalization and in analyzing the results of material balance (MB) analysis. In particular, analysis of the reservoir production behavior and the fluid contact movement over time is essential in narrowing the uncertainty in the parameters used in the model. In building the MB model, two new techniques were proposed and successfully used:
moving linear regression for generating the input pressure for the MB model production-derived relative permeability data for MB prediction.
Applying these techniques resulted in a well-behaved model and a realistic production profile.