bluuebunny/crossref_metadata_2025_split huggingface dataset:
Practical Steps for Successful Identification and Production of Remaining Hydrocarbons Reserves in a Mature Field—Case Study From Tinggi, Malaysia
Authors: Claverie M. , Malek N. A. , Goh K. F. 
Published: December 2007

Abstract
After more than 20 years of exploitation, many of the thick and prolific reservoirs of the Malay basin are depleted. However, field studies indicate that large volumes of hydrocarbons remain located in lower quality but producible layers.
These reserves are the focus of monitoring and recompletion campaigns, to maintain production and extend field life.
Most wells intercept thick accumulations of multi-layered reservoirs, which are produced from dual tubing strings, multiple packers and selectable sliding side doors. In these difficult conditions, special care must be brought to the planning, acquisition and interpretation of monitoring surveys, and to the execution of re-perforation, water shut-off, and other recompletion solutions.
This presentation highlights the practical steps that have led to a successful campaign of identification and production of remaining reserves in the Tinggi field, offshore Peninsular Malaysia.
Water Frac Application in Injectors Improves Waterflooding—An Innovative Approach
Authors: Nainwal S. P. , Das R. , Singh C. B. , Singh S. S. P. 
Published: December 2007

Abstract
Fracturing in water injectors often becomes a pre-requisite to achieve the desired sweep efficiency. The requirement is more pronounced in the injectors with very poor injectivity or poor dissipation. Conventional stimulation techniques like acidisation have not proved to be beneficial. Under such circumstances, a recent foray has been made into the application of water frac.
Water frac is an efficient technique to achieve a limited-length fracture, ensuring a higher sweep efficiency in water injectors. The candidate well is selected after a detailed study by multi-disciplinary team and a customized job schedule is prepared for an initial low-proppant concentration, followed by high concentration at the end to attain higher conductivity near wellbore. Due to zero polymer loading, this technique has the added advantage of low formation damage. There is also saving in chemical and proppant costs. This technique is suitable for not only water injectors, but also effluent disposal wells and polymer flood injectors.
This paper describes the technique and requirements for water frac, along with the case histories. The job design and the results are discussed in details. The benefits accrued have underlined the success of this technique.
Drill-in Fluids for Multi-Lateral MRC Wells in Carbonate Reservoir-PSD Optimization and Best Practices Lead to High Productivity: A Case Study
Authors: Siddiqui M. A. , Al-Ansari A. A. , Al-Afaleg N. I. , Al-Anazi H. A. , Hembling D. E. , Bataweel M. A. 
Published: December 2007

Abstract
Efficient field development requires high quality drill-in fluids (DIF) to minimize formation damage and maximize productivity. This paper discusses the development of least damaging DIFs for multi-lateral Maximum Reservoir Contact (MRC) wells in a newly developed field in Saudi Arabia.
The idea behind the development of DIFs was to avoid fines and polymer plugging by optimizing the loading and Particle Size Distribution (PSD) of fine and medium particles of calcium carbonate.
Several water based DIFs, in the density range of 65 to 70 pcf, were formulated by changing the quantity of fine and medium calcium carbonate with fairly fixed median particle size. These DIFs were tested in the lab on reservoir cores using a dynamic mud flow loop system at simulated reservoir conditions. Tests results indicated 80% return permeability.
Implementation of these optimized fluids in the field with designed practices for maintenance of the quality of DIF during drilling led to high production rates. Twenty five MRC wells so far were drilled using these DIFs. All these wells were production tested with an average PI of almost three times the previously drilled single horizontal wells using the previous DIFs. This high production rate is the result of increased reservoir contact from the multi-lateral wells combined with the optimization of the DIF and the ossociated mud displacement program.
Design and Implementation of a Sand-Control Completion for a Troublesome Shallow Laminated Gas Pay—A Case Study
Authors: Terwogt J. H. , Hadfield N. S. , Van Karanenburg A. A. , Salahudin S. , King K. 
Published: December 2007

Abstract
The Shallow Clastics Field, operated by Sarawak Shell, targets two shallow gas-bearing reservoirs, H1 and H2, at approximately 2,650 ft true vertical depth (TVD). An appraisal/early-producer well with a deviated wellbore was drilled through the H1, H2 targets, and a completion design consisting of a cased and perforated commingled completion inside 9-5/8-in. casing was implemented. The sand-face completion design consisted of a large-OD expandable sand screen with 150 micron weave across the 2 zones. Upon completion, the reservoirs were cleaned up through a temporary well clean-up and test facility to test productivity and evaluate integrity of the downhole sand-exclusion installation. Fines production, possibly due to a failure of the expandable screens, commenced almost immediately upon well bean-up and steadily increased to the extent that the well was deemed unproducible to the facilities.
The failure of the first well caused a re-evaluation of the sand exclusion method employed, which included more extensive core analysis and the completion types that would be suitable for development of the H1/H2 reservoirs. From this review, the operator and a service/ engineering company were able to develop a sand-exclusion method that combined several new technologies needed to effectively complete this reservoir.
To date, four wells have been completed with the new well configuration and sand-exclusion method chosen to address the completion needs. These have been tested, and to date, have proven to be operating satisfactorily.
This paper will review the evaluation that led to the sand-face completion design, the field implementation of the design, and the key installation success factors that were required. Results and a summary of best practices from the initial installations will also be summarized.
A Successful Pilot Application for N2 Foam Flooding in Liaohe Oilfield
Authors: Lin Yuqiu , Yang Guanglu 
Published: December 2007

Abstract
This paper presents a pilot application of N2 foam flooding in a heavy oil reservoir in Liaohe oilfield. After 9 years of steam huff-n-puff, the reservoir pressure is severely decreased, and several portions of the reservoir are unswept. It is urgent to find an alternative method of increasing oil recovery. Nitrogen foam flooding is proposed as a replacement EOR method. It diverts foam into the zones which were bypassed previously, increases the viscosity of the displacing fluid, and decreases oil viscosity.
The N2 foam flooding pilot was initiated in September, 1996 in Block JIN 90 in Liaohe oilfield. The average porosity of the reservoirs is 29.7%, and the crude oil viscosity at original formation conditions is 110-129 mPa.s. By the end of July 2004, 13 pilot patterns have been installed with 47 production wells and 13 injection wells. All the pilots have showed a favorable response till date – exhibiting improved sweeping efficiency, increased oil production, and increased reservoir pressure. They provide a valuable guideline for future development of N2 foam flooding in these reservoirs.
Reservoir Fluid Analysis Using PVT Express
Authors: Khan I. A. , McAndrews K. , Jose J. P. , Jamaluddin A. K. M. , Chetri H. B. 
Published: December 2007

Abstract
Representative reservoir fluid sampling & characterization has become increasingly important, as the exploration activities are moving into the ever-challenging environment around the world. Proper sampling and understanding of the fluid characteristics have become very critical, especially, when dealing with high-risk and marginally economic fields. With a timely and reliable characterization, unnecessary investments can be avoided. Unfortunately, with an unreliable characterization, an economic opportunity may not be pursued. Even worse, an un-economic opportunity may be pursued.
This seminar presents and discusses ways to capture representative reservoir fluid samples and a new fluid characterization technology that can be deployed on-site in the early stages of the exploration and development cycle. We demonstrate the applicability of new surface analysis techniques that allow for rapid, accurate, and reliable measurements of key fluid properties, such as saturation pressure, gas-oil ratio, extended carbon number composition, viscosity, and density, on-site within a few hours of retrieving representative reservoir fluid samples at surface. Consequently, prediction tools used to extend these limited measurements to a traditional "PVT" fluid characterization are also presented. In conclusion, it is shown that the implementation of the technique can reduce the risk associated with making key development decisions.
Solid Expandable Tubular Technology: Case Histories of Value-Adding and Enabling Applications in Sabah Deepwater Campaign
Authors: Miessner Daniel , Ochuko Erivwo , Wenting Wouter , Hopkins Chris , Nijveld Erik , Kaschke Markus 
Published: December 2007

Abstract
Solid expandable tubular technology has seen an impressive uptake in recent years. The technology has the potential to reduce cost, increase production and give access to new reserves. In 2004/2005, Shell Malaysia Exploration & Production installed solid expandables in seven wells, putting itself at the forefront of the technology and adding significant value to the business.
The design philosophy that has been adopted in Shell Malaysia can be described as:Use solid expandables as a planned-in contingency application in case the "trouble zone or event" is encountered. This approach allows for planning of aggressive well designs that fall back to expandables to mitigate problems.Use solid expandables in base-case casing design for deepwater wells with more than 5,000 to 6,000 ft below mud line and with four casing string design.
This paper describes four case histories of solid expandable tubular technology for the Sabah Deepwater exploration campaign in Malaysia. The technology was successfully applied and was very instrumental in achieving the well objectives and delivering a successful exploration campaign.
The key to this success was strong management support throughout the process. This took the form of creating an enabling environment to taking on board new technology and also by supporting actions to build up solid expandable tubular stock in the region to be able to quickly react to opportunities.
Technology support in Malaysia was provided through representation of Shell’s Global Implementation Team for solid expandables, making sure that global lessons were shared and best practices were applied. The Global Implementation Team also worked closely together with the technology provider on QA/QC and job planning aspects, which helped to keep a 100% success record with solid expandables tubulars for Shell in Malaysia.
State of the Art in Coalbed Methane Drilling Fluids
Authors: Baltoiu Len V. , Warren Brent K. , Natras Thanos A. 
Published: December 2007

Abstract
The production of methane from wet coalbeds is often associated with the production of significant amounts of water. While producing water is necessary in order to desorb the methane from the coal itself, the damage from the drilling fluids used is difficult to assess because the gas production follows weeks to months after the well is drilled. Commonly asked questions include: What are the important parameters for drilling an organic reservoir rock that is both the source and the trap for the methane? Has the drilling fluid affected the gas production? Are the cleats plugged? Does the "filtercake" have an impact on the flow of water and gas? Are stimulation techniques compatible with the drilling fluids used?
This paper describes the development of a unique drilling fluid to drill coalbed methane wells, with a special emphasis on horizontal applications. The fluid design incorporates products to match the delicate surface chemistry on the coal, a matting system to provide both borehole stability and minimize fluid losses to the cleats, and a BREAKER method of removing the matting system once drilling is completed.
Field results from three horizontal wells will be discussed, two of which were drilled with the new drilling fluid system. The wells have demonstrated exceptional stability in coal for lengths to 1000 m, controlled drilling rates and ease of running slotted liners. Methods for, and results of, placing the BREAKER in the horizontal wells are covered in depth.
Assisted History Matching for Surface Coupled Gas Reservoir Simulation
Authors: Biswas D. 
Published: December 2007

Abstract
For a gas reservoir, the intake pressures are available at a delivery point and the operator is obligated to supply gas honoring such downstream pressure requirements. As a result, it is imperative that the reservoir deliverability prediction be coupled with the pressure drop in the surface network. Additionally, this coupled system should not only honor the imposed delivery point pressure constraints but also the historical attributes of pressures and rates. In this paper, a modified Gauss-Newton method is utilized in conjunction with a non-linear parameter estimation algorithm to history match a surface-reservoir coupled gas reservoir simulation.
Control Volume Finite Element (CVFE) based reservoir simulator is amenable to unstructured grids to resolve near wellbore and high activity (high permeability channels, fractures) flow areas. The pressure drop in the surface network is modeled using Weymouth's equation of steady state pipeline flow. More importantly, the total system is solved in a coupled fashion thereby enabling the solution to be controlled by surface pressure constraints. In addition, both surface and reservoir decision variables are estimated using a modified Gauss Newton algorithm in the assisted history matching step.
Examples from dry gas reservoir demonstrate the usefulness of this methodology. First, the necessity of coupling surface and reservoir models is highlighted. Next, the computational efficiency of the assisted history matching algorithm as compared to perturbing critical reservoir and surface attributes in a heuristic manner is underscored.
There are three significant contributions of this paper, namely (a) an assisted history matching algorithm proves efficient in comparison to arbitrary perturbation of decision variables (b) a coupled reservoir-surface model renders a more accurate pressure prediction of the total system and finally, (c) an unstructured grid simulator provides the platform for accurate and cost-effective reservoir modeling alternative.
A New Strategy of Brownfield Development in New PT PERTAMINA EP Indonesia
Authors: Kurnely K. , Aprilian S. , Suarsana P. 
Published: December 2007

Abstract
There is big change in oil and gas industry environment since the oil and gas Law No. 22 of 20011 has been stipulated. PERTAMINA, was the only one state oil company, became a limited liability company called PT Pertamina (PERSERO). The exploration and production activities are under PT PERTAMINA EP, a subsidiary of PT PERTAMINA (PERSERO).
85% of the total production in PT PERTAMINA EP is from brownfield assets and total remaining reserve is more than 5 billion barrels oil. Those reserves spread out in 3 regions and 3 business unit areas. Most of the fields are located on shore, produced from primary recovery stage, and declined production around 20% per year.
To increase the national production from brownfield assets under a new management, PT PERTAMINA EP needs new strategies which can be applied in the future. Those strategies include: maximizing of value of the reserve audits which was done in December 2005, new business models in assets development, and managing the risk of new technology implementation.
Modeling of Large Hydrocarbon Compositional Gradient
Authors: Pedersen K. S. , Hjermstad H. P. 
Published: December 2007

Abstract
The paper presents fluid compositions sampled in 6 different depths in a North Sea petroleum reservoir over a vertical interval of 44 m. The fluid column consists of an upper gas condensate zone and a lower volatile oil zone connected by a gas-oil-contact (GOC). The data reveals large vertical variations in the fluid composition.
It is shown that the compositional variation with depth is much higher that what can be explained solely by the action of gravitational forces. The major contribution to the compositional variation originates from the influence of the vertical temperature gradient, which is of the order of 0.026 °C/m. The influence on the compositional gradient from the temperature variation is successfully described using the theory of irreversible thermodynamics.
Exploration Potential of Sinuous (Channellike) Events in Late Cretaceous of Al-Khafji Field, Middle East
Authors: Chakraborty Kalyan , Al-Hajeri Mubarak , Ray Jayanta 
Published: December 2007

Abstract
Stratigraphic trapping mechanism plays a critical role for hydrocarbon entrapment within the Middle-Late Cretaceous reservoirs in the Al-Khafji area. 3D seismic data are acquired aiming at to delineate the stratigraphic and possible strati-structural traps and their associated reservoir setting. Seismic attribute analysis of 350 sq. km. of 3D seismic data of Al-Khafji oil field shows number of sinuous (channel-like) events in the north and north-east of the main Khafji Structure in Tayarat Formation of Late Cretaceous age. The present study utilizes twenty two well data in the crestal part of the Khafji structure to generate a semi-regional facies log, which is turn up-scaled using seismic attribute map. As the area is not covered by any well or other form of data a variogram analysis followed by sequential indicator simulation method was used to derive a facies model between Tayarat and Bahra Formation of Lower Cretaceous age. A volume extraction method was used to extract channel events and integrate into the modeling process to visualize and track channels.
Present study infers a possible definition of facies inside sinuous events and their exploration potential. Porosity estimation using seismic attributes as well as borehole data provides most likely reservoir properties exist in shallow Tayarat Formation. The depth converted and extracted sinuous bodies along with possible porosity profile not only provide a rapid inside into the geology but also indicate further exploration potential particularly in the north-eastern part of the main Al-Khafji field.
A Multi-Scale Approach to Modeling Miscible Gas Injection Sweep Efficiency in a Giant Carbonate, Light-Oil Reservoir
Authors: Hui Mun-Hong (Robin) , Kamath Jairam , Dehghani Kaveh , Fischer Dennis 
Published: December 2007

Abstract
Modeling sweep efficiency of miscible gas injection into a giant carbonate, light-oil reservoir presents technological challenges at many scales, and requires an integrated study at the core, fine earth-model, and coarse flow-model scales.
We first perform phase-behavior studies and core-flood experiments to understand miscibility and sweep efficiency at the core scale. We conduct detailed reservoir-condition experiments on several core samples that are carefully selected to represent the important rock types of the reservoir.
A fine-scale geological model of the reservoir with about 2000 layers is then built. Factors that could impact sweep at the fine scale, such as the Todd-Longstaff mixing parameter and vertical-to-horizontal permeability ratio, are investigated.
A flow-based, nonuniform approach is used to coarsen the fine-grid models by a factor of thirty. The upscaled absolute permeabilities (k*) are computed for the coarse models. We then generate upscaled relative permeability curves (krj*) and bypassed oil saturation (Sorb) values for the upscaled flow grid, and these are used in a modified Todd-Longstaff (TL) miscible simulator. Traditional TL models use straight-line relative-permeability curves (since oil and gas are first-contact miscible) and do not address the need for krj* as a result of upscaling. We apply a novel miscible upscaling technique to generate krj* and Sorb for the coarse-scale models. In our upscaling, we investigate factors such as boundary conditions, inter-well spacing, and the form of the relative-permeability curves to ensure that our assumptions are appropriate for the field problem. By performing scale-up validation studies on sector models, we demonstrate that our overall upscaling approach yields accurate flow results.
The coarse-scale full-field simulation models generated through our upscaling are employed in making predictions crucial to project-planning, economic evaluation as well as to determine the optimal miscible-flooding strategy through sensitivity studies.
Implementing a Framework for Knowledge Management
Authors: Gibby P. J. , Milton N. , Palen W. A. , Hensley S. E. 
Published: December 2007

Abstract
Corporate knowledge is the asset enabling an organization to take effective action, and make crucial decisions correctly. A key challenge for business leaders is how to engage everyone in the processes of knowledge capture, sharing and application. Increasingly, the notion of an internal knowledge economy is becoming a reality for many companies as they strive to become distinctive from the competition.
People and human behavior are at the core of KM. Robust approaches to leverage the collective knowledge of an organization must be adopted entity-wide in order to affect high standards of capture, transfer and application. If KM is to be successful, the organization must be given a clear framework to guide, support, monitor and continuously improve the integration of collective know-how in pursuit of specific business goals.
This paper describes a framework for managing knowledge, which is becoming increasingly adopted within BP's Exploration & Production (E&P) business segment. The Major Projects Knowledge Framework addresses the governance of knowledge as well as the support elements (people, process and technology) necessary to ensure knowledge is applied as needed, when needed and in a format that is usable by others.