bluuebunny/crossref_metadata_2025_split huggingface dataset:
Meeting the Challenges in Alkaline Surfactant Pilot Project Implementation at Angsi Field, Offshore Malaysia
Authors: Othman Mohamad , Chong Mizan Omar , Sai Rithauddin M. , Zainal Suzalina , Zakaria M. Sukri , Yaacob Aisha Ashikin 
Published: December 2007

Abstract
The Angsi field in the offshore Terengganu, Malaysia was identified as the candidate for the pilot project to evaluate the effectiveness of the Alkaline Surfactant (AS) process in improving oil ultimate recovery through the reduction of residual oil saturation. The pilot project entails the injection of AS chemical into Angsi I-68 reservoir and will use a Single Well Tracer Test (SWCT) to determine the residual oil saturation in water-flooded area. This is the first chemical Enhanced Oil Recovery (EOR) pilot project in Malaysia and the results are crucial to support the decision making for a future full field and AS technology implementation in Malaysia.
High reservoir temperature and high water salinity pushes the technical limit of AS application that adds complexity to the pilot design. The implementation of the pilot project in the offshore environment, on an unmanned satellite platform with limited space and facilities provide additional operational challenges to the project team. In addition, the utilization of new and volatile chemicals during the pilot requires an introduction of various field procedures to ensure the operation is carried out in a safe manner.
The paper showcases, the key challenges in the planning and execution of the first offshore AS pilot project in the region. This challenging task demands the multi-disciplinary team to work together to develop the project execution plan with attention to detail during pilot design, planning and operation. As a result, critical parameters such as: treatment sequence, field procedures, equipment requirements and layout, and logistics were considered. The pilot design and procedures that are crucial for a successful pilot operation were developed within the constraints imposed by the offshore environment.
Exploration Performance of Northwest Europe
Authors: Thomas Rhodri 
Published: December 2007

Abstract
Despite having been explored for over 40 years, 3.6 billion barrels of oil equivalent have been discovered in the last five years in north west Europe. On average US$2.4 was spent on exploration for each barrel found in the offshore region. This unit finding cost is comparable to that in the deepwater Gulf of Mexico over the same period, one of the global hotspots for exploration.
The largest volumes of reserves were found in Mid Norway where 1 billion barrels of oil equivalent has been discovered in the last five years. Despite this apparent success, only one of the 11 fields found in the sector is currently expected to be developed before 2012. Gas export capacity from the region remains an issue.
The North Sea itself attracted 75% of the exploration expenditure over the last five years and 2 bn boe of reserves were discovered. Finding costs ranged between US$2.5/boe for the Norwegian North Sea to US$3.5/boe for the UK Southern Gas Basin. Although significantly higher than the US$1.5/boe unit finding costs in Mid Norway, over 50% of these reserves are expected to be developed within five years.
Industry cost inflation and lower discovery sizes have resulted in the finding costs of the last five years doubling from the previous five. However, with a record number of exploration licences being held, US$2.5 billion being spent on exploration last year and substantial finds still being made, there will be many more exploration success stories to come in the region.
Identification of Bypassed Oil For Development In Mature Water-Drive Reservoirs
Authors: Choon Tan Teck 
Published: December 2007

Abstract
An integrated bypassed oil identification methodology was developed and successfully applied to identify and quantify the presence of bypassed oil opportunities in mature water-drive reservoirs in an offshore field in Malaysia.
A 3D reservoir static model was first built as part of the geological review. Reservoir performance review was carried out in conjunction with material balance and average fluid contact movement calculations to understand the drive mechanism and to estimate the current fluid contacts. Performance matching was carried out with an analytical 1D 2-phase Buckley-Leverett model to assess the potential scope of recovery with additional development. Together with dynamic production data animation on 2D maps, a good view of the production-drainage–water influx pattern progression with time was obtained enabling a first pass identification of bypassed oil opportunities. Well performance data were then used to estimate the likely local fluid contacts in the area or sand layers of the completions. The inferred fluid contacts defining the identified bypassed oil were further calibrated with fluid contacts seen in recent wells and crosschecked with 3D seismic features where possible. Bypassed oil-in-place volumes were calculated using the saturation-initialized 3D static model.
The methodology had been successfully applied in reviewing 14 highly matured water-drive oil reservoirs with small to large initial gas caps. The emphasis of this paper is to describe how it can be applied to locate bypassed oil. Although the field concerned had undergone 8 previous phases of development campaigns, application of the approach had led to identification of a substantial number of potential recovery opportunities for further development consideration.
The approach can be applied for systematic identification of bypassed oil opportunities in water-drive reservoirs where detailed dynamic simulation is not justified. It furnishes a comparatively quick fit-for-purpose approach to identify further development opportunities and furnish input for the planning of detail dynamic simulation where the remaining opportunities scope is large.
Subsea Raw Seawater Injection System—A World First
Authors: Rogerson Neil , Laing Tony J. A. 
Published: December 2007

Abstract
Canadian Natural Resources International (CNR) recognises, for the Columba E development, the benefits of using state of the art subsea technology to enhance production by means of optimising raw seawater.
The application of raw sea water injection offers an alternative to conventional topside water injection, minimising many recognised perceived topside challenges; such as topside weight and space constraints, availability of purified water, pipeline transportation from the platform to the satellite and the associated infrastructure installation and commissioning.
Subsea raw sea water injection has been developed over the last decade by Framo Engineering using the proven methods within their subsea pumping technology. Whilst a new application, subsea pumping technology is in operation across a number of fields world-wide with proven reliability and runtimes in excess of 700,000 hours. Extensive testing of key elements of the system further enhanced the confidence in the robustness and reliability of the complete system package. The system package included a Pump Control Module topside, umbilical and the Framo Dual Pump Station. This system approach ensured that there were minimal external interfaces and the technology resided as the responsibility on a single supplier.
This built confidence for CNR to commit to the world's first raw seawater injection system and that such a project could be delivered in an appropriate manner.
Subsea raw seawater injection offered a viable solution, adding significant injection capacity, with a significantly reduced impact to existing production facilities. In addition, the possibility to recover and re-deploy the system later in field life, either on the same development or in another area adjacent to the host adds further to the attraction to the system.
Practical Use of New Microbiology Tools in Oil Production
Authors: Skovhus Torben Lund , Højris Bo , Saunders Aaron Marc , Agerbæk Mikkel , Larsen Jan 
Published: December 2007

Abstract
Culture-based methods of traditional microbiology applied to the microbiological processes involved in souring of oil fields and microbiologically influenced corrosion (MIC) pose a threat of yielding inadequate and contradictory results. Any cultivation step will almost certainly alter the population characteristics and thus also the results on which any evaluation will be based. The need for in situ cultivation-independent methods has over the past ten years facilitated the development of several analytical methods for determination of bacterial identity, quantity, and to some extent function, applied directly to samples of the native population. This development has so far been fairly limited regarding practical application and it has only recently been transferred to the offshore industry.
In this paper, we demonstrate the features and benefits of applying these novel techniques to two situations often encountered in offshore oil production in the North Sea.
The new microbiology tools are based on the detection of genetic material in bacteria. The methods include direct count of specific groups of bacteria with microscopy (e.g. FISH). Additional methods (e.g. qPCR and DGGE) are based on direct extraction of cell genetic material (DNA/RNA). The paper will briefly describe these novel molecular techniques.
By documenting bacterial population shifts related to water breakthrough in a nitrate treated reservoir, we showed that key bacterial populations can be identified and thereby lead to the creation of new and strengthened surveillance strategies on souring bacteria in these systems.
Also, we have shown that by applying these novel techniques to aggressive corrosion attacks, especially under deposit corrosion, molecular techniques are a powerful tool in identifying the most probable corrosion process.
These examples will be described and related to the offshore operation. Special focus will be given to the use of the new and improved microbiological data in relation to designing and testing remedial actions towards oil field souring and MIC.
The Use of Point Cloud Data on Brownfield Projects
Authors: Fairweather Colin K. 
Published: December 2007

Abstract
The first challenge on every brownfield project is to identify the current status of the plant. Drawings and engineering data for the plant are often out of date or unavailable, and many of the older plants have no 3D CAD data available. Various survey techniques have been used over the years, but they tended to be man-hour intensive, produced unreliable data, and were slow in making information available to the design team. Laser scanners delivering point cloud data (PCD) avoid these problems, and, with the ability to reference PCD in the 3D CAD world, make producing a clash-free design in brownfield projects much easier. After testing the Laser Model Interface (LMI) prototype from AVEVA in July 2005, AMEC has now used the LMI on projects offshore around the regions, bringing a new dimension to PDMS brownfield projects in the oil and gas industry. The use of PCD within the PDMS environment has given AMEC the opportunity to reduce project costs, shorten schedules, and improve safety.
Engineering Management Skills: The Present and the Future for Technical Graduates
Authors: Dickson B. R. , Grant C. D. 
Published: December 2007

Abstract
Norman Fortenberry, director of the U.S. National Academy of Engineering's Center for the Advancement of Scholarship on Engineering Education, said that the move toward interdisciplinary engineering curricula is definitely a trend. "It is in response to an increasing consensus within the engineering education community," he said, "but more importantly in the employer community." [1] How does this fit with one of the most relevant degrees to the Oil & Gas exploration and Production Industry-Chemical Engineering?
In reviewing the Personal Skills in Chemical Engineering Graduates, B R Dickson and C D Grant from the University of Strathclyde, Department of Chemical and Process Engineering, Glasgow, Scotland-suggest that the development of skills within degree programmes can meet the needs of employers, yet there is still further work to be done that a relevant post graduate qualification could provide.
In this paper, transferable' (or ‘personal’) skills are defined as the five key skills of: communications; team-working; problem solving; numeracy and IT skills; self-learning. It shows, with some specific examples, that there are ample and varied opportunities to develop these skills within most engineering programmes. The paper then attempts to identify whether the skills possessed by new chemical engineering graduates match the requirements of employers, using two recent comprehensive surveys, including a major survey of chemical engineering graduates with a few years in employment. The paper concludes with some views for further "on the job" training options that could be made available to the technical mangers of the future.
Transient pressure analysis of 4D reservoir system response from permanent down hole gauges (PDG) for reservoir monitoring, testing and management
Authors: Zheng Shi-Yi , Li X. G. 
Published: December 2007

Abstract
One of the key objectives doing well testing is to derive effective reservoir properties, such as permeability, to provide input for reservoir simulation. Traditional approach in well test analysis is first, to separate transient pressure draw down and build ups' due to constant flowing rate, then analyze them by forcing a pre-selected model to derive effective reservoir permeability through an inversion process. However, the results obtained this way are not really dynamic or at most is "pseudo-dynamic", because these are based on the fact that a continuous signal was broken into discontinuous signals. Some information (more than a changed permeability value) of the reservoir system response may already lose, while uncertainties were increased or multiplied in the process of data evaluation and analysis.
This paper presents a new approach, which will allow for continuous reservoir system response analysis and interpretation. Therefore the information derived from such analysis can reflect the real time, dynamic changes of the reservoir. This has been proved more powerful in analyzing transient pressure, particularly for that from permanent down hole gauges (PDG).
Numerical well testing procedures, assisted by neural network method, were used to analyze the data from simulated and field cases in a continuous, systematic fashion. First, the flowing rate history was recovered from the measured transient pressure. Transient pressure histories are then reproduced through simulations of both well test forward model and neural network black box model. A match between measured pressure response (PDG data) and re-produced transient pressure histories will then be made, to achieve the ultimate goal of well testing – real time reservoir monitoring, model calibration and reservoir management. This final matching process was named "guided (by neural network model) history matching".
Removing the Effect of Reservoir Fluids on Porosity Estimated from Seismic Data. A Study on Aboozar Oilfield, North-West Persian Gulf
Authors: Asgharzadeh M. 
Published: December 2007

Abstract
The problem addressed here is based on a study of Ghar reservoir formation in Aboozar oil field. During this study data from 10 vertical wells together with a 3D (3 Dimentional) seismic dataset have been used to investigate the effect of reservoir fluids on porosity estimation.
Due to the existence of a low density HC (Hydrocarbon) in the reservoir, propagation velocity of seismic wave and density of the reservoir is significantly lowered. This will introduce two main problems. First is time to depth conversion of the bended reflectors below the reservoir. The second problem which is the topic of this study is encountered when characterizing reservoir porosity.
Common believe is that the more porosity a rock contains the less AI (Acoustic Impedance) is derived from inversion. As a result more often porosity and AI is cross plotted at the well locations and some times good correlation is achieved. This happens where rock skeleton is very stiff. Where rock framework is loose, estimated AI is strongly affected by the presence of hydrocarbons. In this study, important observation is at the time one applies the linear regression to inversion data. The resulting porosity volume is severely biased by low density fluids inside the reservoir. Above pulled-down OWC (Oil- Water Contact) signature, very high values of porosity are estimated which are erroneous. If we bring more seismic attributes into the analysis and use neural network methods to find the relationship, surprisingly erroneous high porosity zone above OWC is removed; an homogenous porous reservoir rock appears.
As a conclusion, care should be taken when characterizing loose sands containing low density HC. Low AI should not be interpreted as high porosity by use of simple cross plotting. Instead, application of more seismic attributes will remove the effect of hydrocarbon on porosity estimation and results more correlaion between estimated and measured porosity.
Fluvial Reservoir Architecture Modeling and Remaining Oil Analysis
Authors: Jiang Xiangyun , Wu Shenghe , Yu Diyun 
Published: December 2007

Abstract
Most of the mature oil fields in east China are in a stage of high water cut. For these oil fields, the reservoir characterization and remaining oil study need fine scale geological models. A study of reservoir architecture can provide such a fine model. In this paper, we focus on the architecture modeling of fluvial reservoir. Fluvial architecture contains hierarchical bounding surface and architecture elements. This architecture model provides information to analyze the reservoir heterogeneity caused by hierarchical bounding surfaces. Previous architecture studies were conducted on outcrop and modern river deposits. We use the 7th block of Gudong oil field in China as an example to analyze the subsurface reservoir architecture and distribution of remaining oil.
Gudong oil field has been exploited for 30 years. A total of 1070 wells have been drilled and the well space is 150mx150m. Data are abundant and includes core data, horizontal wells, logging data, production data and surveillance data, all of which are used for the reservoir architecture study.
We use the method of "fitting geological model" for the architecture study. Using results of outcrop and modern river deposit studies and paloe-environment analysis, we build the geological patterns of meandering and braided rivers. Based on our analysis, the geological pattern of internal point bar has the following characteristics: (1) parallel-inclined lateral accretion intercalation; (2) 200m width of single lateral accretion body; (3) 3~5 degree dig angle of lateral accretion surface. Our study also shows that the geological pattern of the internal mid-channel bar, which is confirmed by the production information and pair wells data, is asymmetrical intercalation and 2~5 degree dip angle of intercalation surface. Guided by geological patterns, we establish the internal architecture models of Ng522 layer and Ng64 layer in this study area.
Using the internal point bar and mid-channel bar models, we analyze remaining oil and establish different remaining oil distribution patterns. Our analysis shows that the matching relationship between intercalations and perforated intervals is the main factor that influences remaining oil distribution of a sand body. This provides a new way to find remaining oil in a mature oil field.
Predicting Accelerating Subsidence Above The Highly Compacting Luconia Reservoirs, Offshore Sarawak Malaysia
Authors: Dudley J. W. , van der Linden A. J. , Mah K. G. 
Published: December 2007

Abstract
Sarawak Shell Bhd has a number of offshore gas fields that produce from the Luconia carbonate formation, which can exhibit high compressibility pore collapse deformation. Recent accelerated subsidence has been observed at several of these fields, which extrapolates to final subsidence values well above previous estimates. This paper describes a geomechanical study involving core work to determine if the Luconia formation compressibility is sensitive to brine flow from the rising aquifer, and a 3D geomechanical finite element model developed to predict future subsidence and lateral movements for the F23 platform.
Compaction tests were performed on Luconia core from three different gas fields. Tests on twin plugs were conducted - one plug undergoing a standard uniaxial constant-lateral-strain compaction test, while it's twin has several pore volumes of simulated formation brine flowed through it (at virgin in-situ stress conditions) prior to the compaction loading. Four sets of compaction tests on twin plugs were completed. The higher porosity samples showed characteristic pore collapse behavior, consistent with previous measurements on Luconia mouldic limestone core. No sensitivity to brine flow was observed. In situ compaction logs in the field also do not show increased compressibility in sections flooded by the rising gas-water contact. The geomechanical model uses a relatively simple structural model comprised of two overburden, the Luconia carbonate, and one underburden formations. A non-linear deformation model for the Luconia formation captures the accelerating pore collapse response observed in the core and in-situ compaction measurements. The model is calibrated to GPS-measured platform subsidence, and is consistent with measured core and field compaction properties. The results predict that platform subsidence rates with depletion would level off, with a maximum subsidence of 18.5 +/− 1 feet at an abandonment pressure of 300 psi. Platform subsidence in the two years following the work continues to follow the predicted values.
This work illustrates the importance of integrated geomechanical core testing, field monitoring measurements and modeling to accurately predict compaction and subsidence effects in highly compacting environments.
Saltire Field: Flying The Flag for Mature Field Redevelopment
Authors: Ballantyne Grant , Daini Olugbenga , Mills Rob , Morrison Kerr , Slater Julian 
Published: December 2007

Abstract
Interest in the operation of mature fields in the North Sea has significantly increased due to the quantity of reserves still locked away in these fields. The wave of change in operatorship from the major oil companies to independent oil companies combined with the current high oil price has rejuvenated interest in recovering more oil from mature fields.
This paper shows how good oil field practice can enhance the production from a mature platform. A three pronged approach of facilities reinstatement, a concerted wellwork campaign coupled with good reservoir management has resulted in increased oil production from the Saltire platform.
The wellwork campaign consisted of low capital well interventions such as the identification and preferential isolation of high water cut zones, gas lift optimisation and strategic optimisation of available water injection to enhance sweep efficiency.
The incremental production achieved on Saltire proves that minor well interventions, often viewed in isolation as non material, when planned and executed as a concerted campaign can result in a significant increase in oil production and extend life of field by many years.