bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Laboratory Investigation of Water Abatement Chemicals for Potential Use in the Wanaea Oil Field
Authors: Sidiq Hiwa H. , Amin Robert , Kennaird T. 
Published: June 2009

Abstract
The disadvantages of water influx into a producing well include reduced relative permeability to hydrocarbon and increased expenses for both water handling and corrosion control. An effective water control technique is, therefore, highly desirable. One potential solution for reducing excessive water production is the injection of "Relative permeability modifier" (RPM) chemicals into producing wells. The work described in this paper is concerned with finding a highly selective chemical to reduce water production without affecting oil production. Presented herein are results of laboratory tests using relative permeability modifiers in conjunction with core samples from the Wanaea field.
The oil producing Wanaea field is operated by Woodside Energy offshore Western Australian. Some of the wells suffer from high water cut, therefore the introduction of a relative permeability modifier (RPM) has been considered.
Four RPM chemicals were tested with core plugs taken from Unit II of well Wanaea-3 (core depth 2832.00 to 2844.50 m). Laboratory experiments were conducted on 4 reservoir core plugs, with air permeabilities ranging from 158 to 334 md and porosities from 16.4 to 19.9%. The objective of the tests was to assess the effectiveness of selected RPM's in selectively reducing water production.
The experimental results demonstrate that the chemicals were variably effective in reducing the relative permeability to the water phase, but they also variably affected the relative permeability to the oil phase.
Lean Duplex Materials for Line Pipe Applications in Sweet and Slightly Sour Environments
Authors: Rommerskirchen Iris , Lemken Sven , Hoffmann Reinhold , Butting H. 
Published: June 2009

Abstract
For some years, lower alloyed austenitic-ferritic stainless steel grades have been developed, which are summarised in the „lean duplex"- family of alloys. So far, lean duplex materials have been mainly used as plate material for construction of containers and vessels in the pulp and paper business as well as in architecture and construction.
As they are lower alloyed in nickel and molybdenum compared to standard duplex grades, lean duplex grades can offer economically interesting advantages combined with a higher degree of technical reliability compared to supermartensitic stainless steels.
Aim of the present study was to figure out, whether lean duplex grades can close the gap between supermartensitic steels and standard duplex stainless steels with regards to weldability, structural stability, mechanical properties as well as corrosion behaviour in typical media for the oil and gas industry.
Downhole Fluid Analysis Integrating Insitu Density and Viscosity Measurements - Field Test from an Oman Sandstone Formation
Authors: Khalil Mosleh , Rumhi Huda , Randrianavony Mahaly , Mullins Oliver C. , Godefroy Sophie 
Published: June 2009

Abstract
The new generation of wireline formation testing fluid analyzer presented in this paper integrates in-situ optical fluid analysis device with a oscillating mechanical sensor providing downhole density and viscosity measurements in real-time at reservoir conditions. Fluid density is measured primarily by measuring corresponding changes in the vibrational frequency of the oscillator while viscosity is determined primarily by monitoring the decay time of the resonance. The formation testing wireline tool was utilized in combination with the new optical fluid analyzer to identify the fluid types downhole in the complex lithology reservoir drilled with an oil based mud. Focused sampling was essential to reduce mud contamination thereby enabling accurate determination of fluid compositions and properties such as density and viscosity.
The in-situ optical fluid analyses provide the quantitative hydrocarbon compositions in terms of C1, C2, C3-C5, C6+, CO2 along with the water fraction in both oil based mud (OBM) and water based mud (WBM) wells. Gas Oil Ratio (GOR) or Condensate Gas Ratio (CGR) is also computed from the optical analyses. The density measurement provided by the mechanical sensor brings additional value in comparison with pressure gradient analyses and is critical to evaluating thin, tight or depleted flow units. The viscosity measurement, the first downhole measurement of its kind, is particularly important as viscosity is one of the key fluid properties that directly affect the producibility of the flow units.
A field test was conducted in an onshore reservoir in the Sultanate of Oman. It was performed in a well having oil, gas and water zones. As a result of the quantitative downhole compositional analyses and fluid property measurements, single phase samples with low mud filtrate contaminations were collected. The PVT laboratory results served as a valuable comparison for the fluid composition as well as density and viscosity measurements.
Solid Expandable Technology for Zonal Isolation of Loss Circulation Formation: Case Study Shuaiba Formation
Authors: Ekpe J. , Alexeenko A. , Al-Thuwaini J. , Emad M. , Khanlarov R. 
Published: June 2009

Abstract
The frontier exploration drilling campaign in the Kingdom of Saudi Arabia for LUKOIL Saudi Arabia Energy Ltd started in January 2006. LUKSAR, a joint venture between Lukoil & Saudi Aramco, took pragmatic approach to project management. A careful analysis of campaign challenges with proper planning to meet the drilling campaign targets. One major challenge was to stick to well program to ensure well targets are met and exploration objectives achieved. The reduction of wellbore diameter due to hole problems during well construction has always posed a great challenge to well completion. Having said that, there are few technologies at present that provide the capability to execute well intervention/work-over in slim hole wells and where there are available, they usually cost a fortune. The restriction created in reduced hole sizes typically results in a complicated drill stem testing program (DST), formation fracture pressure limitation, decrease in production rate due to restriction in tubing selection and high intervention cost. On Luksar Expl well #4, the above mention challenge was a reality. While drilling, encountered severe loss circulation in Shu'aiba carbonate formation compounded with sloughing shale problems in the shallower Wasia formation. As a result, it became difficult to drill further and set planned casing at bottom. Utilizing expandable tubular across loss circulation zone enabled Luksar to restore the original well casing design.
Evaluation of Miscible and Immiscible Gas Injection in One of the Iranian Fields
Authors: Delfani S. , Mortezapour A. , Firouz A. Q. , Shadizade S. R. 
Published: June 2009

Abstract
A compositional reservoir simulator has been used to determine the reservoir management and production strategies to optimize the oil recovery from an offshore low porosity, low permeability carbonate reservoir with permeability of 1–3 md and porosity of 5–20%. This reservoir is a candidate for an EOR process, because the reservoir production rate has been declined rapidly to about half of the initial production rate within four years. The injection techniques that were used in this study include gas injection with different fluid that it causes miscible and immiscible process. Specific strategy that was used includes the use of injectors and producers. This well configuration has been shown to yield the best oil recovery compared to other well configurations. Simulation results show that the most economical method to produce this reservoir is miscible gas injection. This production strategy has resulted in better efficiency and therefore higher oil recovery and good economics.
New Technique to Cure Losses in UeR Formation in South Oman Field—A Case Study
Authors: Mahapatra Shrikant K. , Stevenson Eddie , Al Fadhli Abduallah 
Published: June 2009

Abstract
As part of the field development plans for the South Oman oil field, four trial wells have been drilled to assess the impact of steam injection on productivity and recovery. At the outset of the trial, it had been determined that lost circulation was a major drilling problem in the UeR formation in this area. Lost circulation (LC) is a phenomenon wherein circulating drilling fluid is lost to fractures and pores in the rock formation rather than returning to the surface through the wellbore annulus. If not corrected beforehand, the lost circulation that occurs during the cement job can lead to incomplete sealing of the annulus, which may require remedial cementing to attempt to fill the annulus. Moreover, voids in the annular space are potentially disastrous, especially in steam injection wells, because of the expansion of the pipes when exposed to elevated temperature during the steam injection. Typical reported LC-based problems such as buckling of casing, bi-axial collapse, and wellhead growth are the results of poor cement coverage behind casing strings.
The normal practice is to stop the losses either with loss circulation material (LCM) pills or with cement plugs of a recipe different from that used to mix the original slurry. These methods were tried in the first well in this campaign; however, they did not give satisfactory results. As an alternative approach, an improved fluids train was programmed that would maximize the benefits of the cement slurries. This new technique was successfully applied and subsequently used in the next three wells in the campaign. The same technique was also used successfully in subsequent wells drilled in the field. As a result of the successful curing of losses, the production casing could then be cemented to surface. The successful curing of losses with the new technique has also led to rig-time savings, and bond logs also indicate good cement bonds.
Environmental Study for Two Gas Pipelines Through the Baltic Sea
Authors: Valeur Jens Rosendal , Larsen Joern Bo , Stroebaek Neel 
Published: June 2009

Abstract
Two gas pipelines connecting Russia and Germany through the Baltic Sea are planned to be constructed during the period 2010-2012. The pipeline system will enable an annual transportation of 55 billion cubic metres (bcm) of natural gas from Russia to the European gas grid.
Comprehensive studies of the potential environmental impacts of the project have been carried out. Special attention has been given to the fact that the Baltic Sea is a unique and vulnerable environment. It can be considered the world's largest estuary, with marine life adapted to the brackish water environment and with limited water exchange with the surrounding sea through the Danish straits.
Valuable experience from major bridge and tunnel construction works across the Danish straits during the 1990s has been used in order to carry out an assessment of the environmental impact of the gas pipeline project and in order to design the construction works in an environmentally friendly way.
The environmental aspects of the various phases of the pipeline project have been identified, and their environmental significance has been assessed. A rating system for classifying the environmental impacts has been developed. Classification has been carried out based on type of impact and extent in terms of space and time.
The environmental aspects of the project have been integral to the planning phase to ensure that the design of the pipeline system is environmentally optimised. A major task has been to identify the optimal route, taking into account both the important nature areas in the Baltic Sea and the special precautions related to the presence of dumped munitions in parts of the Baltic Sea. The environmental analyses show that the pipelines can be constructed, operated and decommissioned with no long-term impacts on the marine life of the Baltic Sea.
Seismic and High-Resolution Sequence Stratigraphy of the Upper Cretaceous Simsima Formation, Onshore Abu Dhabi Oil Field, United Arab Emirates
Authors: Hozayen M. A. , Strohmenger C. J. , Mueller K. , Al-Marzouqi S. H. , Shuaib M. 
Published: June 2009

Abstract
An important carbonate oil field, located onshore Abu Dhabi, has been producing from the Upper Cretaceous (Maastrichtian) Simsima Formation since 1983. To optimize and increase production of the field, seismic and high-resolution sequence stratigraphy was integrated by tying fourth-order, high-frequency sequences identified from core to 3-D seismic data.
To establish the sequence stratigraphic framework, a new detailed sedimentological and high-resolution sequence stratigraphy study had been carried out, integrating approximately 7,000 feet of core material, approximately 3,500 thin sections, and all available well-log data from 46 wells. Core description, together with semi-quantitative petrographic examination of thin sections, established a new depositional model for the Simsima Formation. Sixteen lithofacies types (LF1 to LF16) representing a wide variety of depositional environments, ranging from upper ramp, rudist-bioclastic shoals to open marine mid to outer ramp mud-dominated settings. The newly developed, high-resolution sequence stratigraphic framework suggested that the Simsima Formation comprises one complete third-order composite sequence and the transgressive systems tract of an overlying second third-order composite sequence. These third-order composite sequences include seventeen high-frequencies, fourth-order sequences (HFS). HFS-1 to HFS-12 build the older third-order composite sequence, HFS-13 to HFS-17 form the transgressive system tract of the overlying, younger third-order composite sequence. 3-D seismic cross-sections show that fourth-order high-frequency sequences HFS-1 to HFS-6 of the older third-order composite sequence clearly show onlap on a pre-existing high (pre-Simsima unconformity surface), whereas the top part of the Simsima Formation (high-frequency sequences HFS-13 to HFS-17) show various degree of erosion. The established high-resolution sequence stratigraphic framework provides the layering scheme for the next generation Simsima 3-D static model, which will be used as input for the reservoir flow (dynamic) model.
Reservoir Rock Typing from Crest to Flank is There a Link?
Authors: Basioni R. E. Mahmoud , Negahban R.E. C. Shahin , Dawood S. R. E. Ahmed , El Mahdi S.R. E. Ahmed , Bahamaish T. L. Jamal 
Published: June 2009

Abstract
Minimizing uncertainty associated with predicted log water saturation can be best achieved through the integration of log analysis (formation evaluation) and capillarity (core measured high pressure mercury and oil/water drainage capillary pressure data). Further reduction of uncertainty in predicted formation water saturation requires; first the most probable log porosity solution interpretation; second the most probable log porosity/permeability relationship (match core measured values); and third a quantitative capillary pressure model that represents measured high pressure mercury and oil/water drainage capillary pressure data.
This paper is a continuation of previous work done using the classical Leverett-J method (Leverett 1941) in integrating capillary pressure data with routine core analysis and petrophysical rock types to generate a robust model for predicting formation water saturation profiles. Two datasets were used in the application of this method in two phases. Phase 1 was accomplished by using the first dataset, which is for a crestal well, in characterizing reservoir rock types by the assignment of capillary pressure curves to their corresponding rock types. This process was accomplished by grouping rock types according to discrete ranges of the interval speed which is defined as the square root of core measured permeability divided by porosity (k/ϕ) data. Each range of the interval speed will have a corresponding Leverett J function from which water saturations will be interpolated according to its respective height above the Free Water Level (FWL) (using the log predicted permeability-porosity ratios). In phase 2, the second dataset, which is from a flank well, was used to quality check the rock typing interpretation and to aerially map the change in reservoir rock types when going from crest to flank. One of the main findings from this work is the importance of quantifying the cementation process that took place in rocks' post-deposition.
In the absence of clear fluid contact, a trial and error method was followed to adjust the FWL until a good agreement between the log predicted water saturation and the predicted water saturation from the capillary pressure correlation was reached. The error in averaging was minimized by increasing the number of rock types (minimizing the ranges of interval speed) using a large number of measured high pressure mercury and oil-water drainage capillary pressure data. Furthermore, this paper presents a comprehensive comparison of the log derived and model predicted water saturations.
Building a Deterministic 3D Model of Tar Mat deposits in a Carbonate Reservoir in a Geologically Consistent Manner: A Case Study from Offshore Abu Dhabi
Authors: Ruelland Philippe J. , Lehmann Christoph T. , Al Hosany Khalil I. , Cobb David O. 
Published: June 2009

Abstract
The presence of a Tar Mat in carbonate reservoirs in the Gulf region is common. Tar Mats occur on different scales from thin seams along stylolites and porous intervals to thick successions within the reservoirs. In the latter case, it raises important issues regarding field development options and well placement optimization. The Tar Mat in Field A, offshore Abu Dhabi, was detected in the first exploration well in 1969. In the 1970s and 1980s, 7 additional wells were drilled; the most recent well was drilled in 2007. Tar Mat sections were identified in all the appraisal wells.
The top of the Tar Mat can be clearly seen in the cored reservoir sections where it plugs the larger pore space. The bottom of the Tar Mat is not as simple to determine visually. Detection of Tar Mat is less reliable in cuttings and logs especially in tight zones and in the sections with lower reservoir quality. Thin section observations on the Tar Mat interval in the various wells appear to show that it is not present in heavily calcite cemented intervals related to paleo-water legs.
This hypothesis on the Tar Mat generation is based on Gulf analogues, in which the Tar Mat reflects a fossilized paleo-oil-water contact. In Field A, the top and bottom Tar Mat surfaces are not flat and their deformation reflects the growth of the structure after Tar Mat generation ended. The bottom Tar Mat surface is considered as the latest paleo-oil-water contact preserved in the field. These observations help in building a 3D model of the Tar Mat away from well control and, therefore, decrease the uncertainty in predicting the distribution of Tar Mat in the field. Better predicting the distribution of Tar Mat will have a significant impact in the successful development of this field.
Harnessing the Information Mammoth… New advances in data management in Engineering IT
Authors: Gibbons Steve 
Published: June 2009

Abstract
Today's oil & gas companies are struggling to meet the world's growing demand for energy. Oil & gas installations are getting ever more complex. New production capacity must be brought on line in ever-shorter timescales. More and more data is being created, bringing with it the challenges of how to access, share and control this information ‘mammoth’.
The cost of down time, whether planned or unplanned, rises with the oil price; production facilities require continual modification to extract more oil from depleting reservoirs, while squeezing more output from ageing downstream plant can incur operational and safety risks. There has never been greater need for better exploitation of the information embodied in oil & gas assets.
A number of factors have increased the information mammoth challenge: The increased volume and diversity of available information. IT advances have made it ever easier to create data; more and more applications and systems generate more and more data. Plants typically use many different, incompatible applications, so the information within them is effectively locked up in ‘silos’ – disconnected data formats that simply don't communicate with each other or make themselves universally available, and which are never uniformly updated.A stricter regulatory environment. This brings an increased need to audit business processes for compliance, and to be able to produce, at a moment's notice, reports, drawings, diagrams and other data to satisfy regulatory assessors' ever-growing demands.The continued trend towards larger multi-partner, multi-contractor and -subcontractor projects. How can data be shared from the very start? How can we make sure that data is updated correctly and that everyone has access to the right data at the right time? In short, how do we control the creation and dissemination of data?A change in demographics, leading to a shortage of skilled and experienced staff. Enormous experience and knowledge are locked away within a dwindling pool of highly skilled engineers. How can we unlock that experience and make it available to new trainees?
A Practical Guide for Identifying and Solving Air Cooled Heat Exchanger Performance Problems in the Field
Authors: Ellmer Marc 
Published: June 2009

Abstract
Well over 85% of all air cooled heat exchangers (ACHEs) in operation do not perform to their specified design values or end user requirements. As a result of this, during hot summer days, the product flow has to be reduced to achieve the required product temperature or pressure in the column.
Production losses during these days can reach as much as levels between 20 to 40 %. This can lead to losses amounting as much as US$ 500,000 to US$ 1,000,000 per year for one single limiting air cooler on a critical unit.
In this paper, we would like to offer you a practical guideline enabling your organization to identify basic air cooler problems and offer you also a few options to get more out of your ACHE without having the need for brand new air coolers or adding new bays.