bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Wireline Sampling Technique Enables ZERO Contamination Sampling: A Case Study in a Challenging Sampling Environment
Authors: Kundu Dibyatanu , Kumar Sanjay , Joshi Sameer 
Published: December 2007

Abstract
Cairn Energy India Pty. Ltd (CEIL) discovered Bhagyam field in RJ-ON-90/1 Block in July, 2004. With objectives to provide better bore hole stability and to determine accurate Sw (water saturation) from the cores collected while drilling, CEIL used Oil Based Mud to drill wells in this field. The sandstone formations in Bhagyam are characterized by high permeability both in vertical and radial directions. There is a high degree of variation in the properties of formation fluid as one progresses from the oil water contact to the crest of the structure. The formation fluid is very high in wax content.
Sampling of formation fluid using traditional wireline formation testers becomes very complicated in view of these factors. In fact, 20 samples were acquired from this region and the laboratory deemed all of them non-representative. The OBM contamination levels in all these samples were more than 15%. It was thought that a focused sampling concept could be applied under such circumstances.
Quicksilver* probe, which enables focused sampling, was used for acquiring representative formation fluid samples in two wells in Bhagyam field. A total of 18 samples were acquired in these two wells. Out of these 18 samples, 6 were contamination free and most of the samples were suitable for carrying out further PVT analysis.
This sampling technique is one of the very first to be used in India and in fact results delivered by this technique are one of the very best as compared to other sampling techniques employed world wide. This paper deals with the operational and interpretational aspects of the Quicksilver* tool. It also brings out the comparison between contamination results obtained from SOCM (Synthetic OBM Contamination Monitoring method) and actual laboratory data.
Planning for Regional EOR Pilot for Baram Delta, Offshore Sarawak, Malaysia: Case Study, Lesson Learnt and Way Forward
Authors: Sudirman Sharizan B , Samsudin Yuzairy B , Darman Nasir Haji 
Published: December 2007

Abstract
The BDO EOR feasibility study conducted in 2004 by PETRONAS and Sarawak Shell Berhad (SSB) identified a potential incremental recovery of over 250 MMstb from the Baram Delta Operation (BDO) fields1. This incremental oil can be realized from CO2 injection under miscible and immiscible conditions. On average, this represents an additional 12% incremental recovery above the base case of water flooding.
The regional CO2 injection covering nine (9) fields requires a very significant investment of new CO2 infrastructures and injection facilities. To mitigate the risk involved and to prove the commercial viability of the project, a regional pilot was proposed. The pilot, which will be implemented in Baronia RV2 reservoirs, will serve as a basis to formulate the way forward for CO2 injection in the whole BDO region.
Several extensive evaluations were carried out to come up with an optimized pilot design. This includes building full field compositional fluid flow simulation model for CO2 miscible flood predictions and sensitivities, streamlines analysis to identify suitable well pairing, and MMP / interfacial tension measurements in the laboratory. The proposed observation pilot were specifically designed to address several issues such as determination of current oil saturation, waterflood residual oil saturation, residual oil saturation after gas flooding and evaluation of the vertical sweep efficiency. The pilot will also serve as an opportunity to acquire additional data through extensive coring, logging, and fluid sampling programs.
This paper outlines the methodology used in the developing the most cost-effective pilot at Baronia RV2 reservoirs that could potentially lead to economic maturation of new reserves in the whole of the BDO area as well as formulating the most comprehensive monitoring and evaluation techniques of the pilot.
Development of Highly Contaminated Gas and Oil Fields, Breakthrough CO2/H2S Separation Technologies
Authors: Klaver Theo 
Published: December 2007

Abstract

Description
Shell Global Solutions International B.V ("Shell")1 has been involved for many years in the development of new technologies to separate CO2 and H2S from highly contaminated natural gas streams. This program has been significantly accelerated in recent years and major milestones have been achieved. The program focuses on technology solutions that are critical to develop (stranded) contaminated hydrocarbon gas and oil fields.
Several key technical challenges in the development of highly contaminated gas & oil fields have been overcome with new technologies developed by Shell. These challenges include: contaminant separation at minimal energy consumption and losses at minimum capital investment.
This paper will present these challenges and introduce new technologies that can help to reduce project development cost by as much as 40% compared to conventional technologies

Application
External studies (Steiner, 2005) estimate a global (recoverable) resource of some 500 B boe ( = 3000 tcf), as per bar chart figure 3 below, of gas that is ‘contaminated’ by the previously defined levels H2S and/or CO2. These resources will require specific technologies to develop these fields economically. The bulk of these resources are in the Middle East, Canada, CIS, Asia and Australia. In general, one could say that the predominantly H2S contaminated fields can be found in the northern Americas (Canada), the Middle East (Abu Dhabi, Kuwait, Oman, Saudi Arabia, Qatar), and the Caspian regions (Kazakhstan, Russia). The indicated size exclude resources that could be accessed via H2S / CO2 Enhanced Oil Recovery (EOR).
The application of the newly developed technologies will be in the area of contaminated gas fields. With new technologies highly, contaminated gas fields can be economically developed to remove the contaminants from the hydrocarbon gas and re-injection of the contaminants. Since conventional technologies become less economic at increasing percentages of contaminant, the new technologies are specifically targeted at high concentrations of contaminants (&gt;30%). The new technologies aim for efficiencies above 85 %, where efficiency is expressed as a percentage of hydrocarbon sales gas divided by the hydrocarbon feed stream. (Losses are due to fuel gas and hydrocarbons left in the contaminant stream)
The Changing Face of the Oilfield Worker: Preparing for Generation Y
Authors: Rajan Surya 
Published: December 2007

Abstract
In the mid-eighties Generation X was just starting to trickle into the workforce. Concurrently, the oil industry was starting to enter another cyclical downturn. Fairly impossible to discern at the time, that synchronicity led to profound, far-reaching consequences.
Generation X, roughly defined as those born between 1965 and before 1980, presented a dilemma to businesses at large. Departing significantly from prevailing norms, they pursued work-life balance, flexibility, and independence. The most noteworthy aspect, though, was what they did not have: sufficient numbers to replace equivalent age demographics that they would eventually replace. Coupled with the economic downturns in the oil industry at the time, this posed double jeopardy: not only did we present a bleak and unattractive image, but we were also unable to open our doors to very many aspiring entrants. Resulting hiring deficits in the oil industry lasted for over a decade, and manifests now as the "Big Crew Change" as experts have called it. A challenge to the industry as a whole, it also translates into an unprecedented set of exciting opportunities for the latest incumbents, Generation Y.
Roughly classified as the age demographic born between 1980 and 1999, Generation Y is being looked upon as the "bridge material" to not only fill the gaps in the workforce caused by the Generation X population deficit, but to also act as the conduit for transfer of knowledge and experience as Traditionalists and Baby Boomers continue to retire or approach retirement. Success in this transition is a strategic imperative for the industry today. There are many aspects of potential change that must be examined to ensure sustainable influx and retention of Generation Y workers. This analysis explores key opportunities for change in the industry, along with the pivotal role that Generation X can play in this evolution of the oilfield workforce.
Risk-Based Candidate Selection Workflow Improve Acid Stimulation Success Ratio in Mature Field
Authors: Kartoatmodjo G. , Caretta F. , Flew S. , Jadid M. 
Published: December 2007

Abstract
In mature, multi layered reservoirs with commingled, dual string, and gravel packed completions, selecting reliable acid stimulation candidates has always been a challenge. Achieving a high success ratio under these conditions requires a risk-based selection process, supported by reservoir understanding and characterization.
As the traditional workflow, acid stimulation candidate selection starts with a thorough production performance review. Production history is provided on a string-by-string basis, and nodal analysis modeled based on production performance. Perforation and completions are evaluated to identify any damage. Logs are then reviewed to evaluate mineralogy and petrophysics. In this workflow, candidate selection is refined by reservoir modeling to predict the production gain in field level and production decline prediction. A decision and risk analysis is conducted with a strong emphasis on range of probability evaluates all possible outcomes associated with success and failure ratio. An economic analysis is evaluated based on risk analysis. This workflow is developed and tested in Bokor field, off the coast of Sarawak, Malaysia.
After acid stimulation campaigns spanning over 6 reservoirs, the results have yielded to 40% oil production gain. Six strings showed an increment in oil rate, a reduction in water cut and an increase in productivity. Overall, the fine tuned acid job design combined with visco-elastic surfactant diversion technique proved to be effective.
This paper presents the comprehensive workflow developed and implemented by the Bokor Project Management Team (BPMT) encompassing all the components necessary to deliver a risk based decision and therefore the optimum results.
Anomalous diffusion behavior of CO2 in the macromolecular network structure of coal and its significance for CO2 sequestration
Authors: Mazumder Saikat , Bruining Johannes 
Published: December 2007

Abstract
This paper gives an analysis of the Thomas and Windle model, which is also proposed to describe anomalous diffusion of CO2 in coal and its relation to matrix swelling. Anomalous (case II, super-) diffusion, which incorporates the swelling of coal matrix by the sorption of CO2, occurs due to coupling of diffusion and relaxation mechanisms. The relaxation process is related to the transition of coal from glassy to a rubbery state, i.e., to swelled coal. For reasons of easy reference we present a shortened derivation of the Thomas and Windle model, which was originally derived to describe diffusion in polymers. Analysis of the model equation shows that super-diffusion is only a transitional effect. i.e., there is (1) an initial phase in which the relaxation process dominates, (2) a transition phase that exhibits anomalous diffusion and (3) a long time phase that shows the typical square root of time behavior of an ordinary diffusion process. The significance of the transition phase depends on the parameters, in particular the size of the coal particles between the cleats.
A Case Study: Using Wireline Pressure Measurements to Improve Reservoir Characterization in Tight Formation Gas—Wamsutter Field, Wyoming
Authors: Schrooten R. A. , Boratko E. C. , Singh H. , Hallford D. L. , McKay J. 
Published: December 2007

Abstract
Improving recovery in tight gas reservoirs typically mandates infill drilling programs. Characterization of reservoir pressure depletion and sand body continuity are fundamental to determining the economic viability of these projects. An elusive challenge has been to gather fit for purpose pressure data in these tight formations due to the nature of the rock and the granularity of the data necessary. This case study summarizes results for a wireline pressure data collection campaign on twenty wells where more than 120 pressure measurements were taken in the Wamsutter Field, Wyoming.
The observations presented in this case study serve as a model for what can be achieved in similar fields using these techniques. The conditions and limits of pressure data applicability in this environment are set forth.
In tight gas reservoirs new generation wireline tools which employ extremely precise pretest mechanisms can achieve the required data acquisition objectives more efficiently than long-established methods. However, wellbore conditions and data acquisition procedures can greatly influence the quality and limits of data application. A field description, operational lessons learned, data quality observations and conclusions are presented.
This case study represents a statistically significant collection of detailed pressure data in a partially developed, complex, tight formation gas field collected with new generation wireline technology. Operational, interpretation and application recommendations for wireline pressure measurements in the tight gas environment are included.
Bioremediation of Oil Contaminated Soil at South Santhal CTF, Mehsana, India: A Case Study
Authors: Mandal Ajoy Kumar , Sarma Priyangshu Manab , Dwivedi Manish , Swaleh Abu , Lal Banwari , Agnihotri A. , Hazra U. S. , Doraiah A. , Patidar S. S. 
Published: December 2007

Abstract

Description of the material:
The petroleum industry effluents, oily sludge and oil spills cause a serious threat to the environment as their constituent compounds have toxic, mutagenic and carcinogenic properties. With the stringent regulatory norms and environmental obligations, safe disposal of these hazardous wastes is a serious problem. Various conventional methods are available for disposal of the same, but all of them are having one or more disadvantages. Biological methods have been well reviewed and acknowledged for reclamation and remediation of environments contaminated with petroleum hydrocarbons. The paper describes a field case study on the bioremediation of oil contaminated soil at an installation of Oil and Natural Gas Corporation Ltd. (ONGC), India.

Application:
A bacterial consortium was developed by assemble of four species of bacteria which could effectively biodegrade different fractions of total petroleum hydrocarbon. Using this bacterial consortium huge quantity of oily sludge and large area of land contaminated with oil spills can be treated for safe disposal.

Results, Observations and Conclusions:
In the present study, total 1500 tonnes of oil-contaminated soil was undertaken for treatment by bioremediation techniques at three sites of South Santhal central tank farm area (CTF), Mehsana Asset, ONGC, India. Within 135 days of treatment, the total petroleum hydrocarbon (TPH) of the oil contaminated soil was degraded by 90.98%, 92.08% and 91.47% at Site – I (Well no. 1), Site – II (Well no. 205) and Site – III (Well no. 206) respectively. Whereas at the control site, without treatment by bioremediation techniques, the degradation of TPH was negligible. Hence biodegradation technique has been proved to be an effective method for treatment of oil contamination.

Significance of Subject Matter:
This study has helped the ONGC authorities to identify an environment friendly method for disposal of oily waste. The bioremediation study of oil-contaminated soil by applying microbial consortium is an ongoing investigation and the results are highly encouraging.
Importance of Economic and Risk Analysis on Today's Petroleum Engineering Education
Authors: Cunha J. C. 
Published: December 2007

AbstractGraduate students in a master or PhD program tend to naturally concentrate their efforts on the understanding of theoretical issues related to their main research area of interest. This will frequently lead to a cultural shock when they, after concluding their program, enter or return to the job market.Commonly these professionals are asked to analyze, develop and/or implement projects based not only on technical premises but also on solid and very well supported economical feasibility studies. Frequently the common graduate academic background does not prepare students for those tasks.The importance of a thorough understanding of economic issues and associated risks is even more noticeable in the oil industry, where uncertainties related to oil and gas reserves, prices and government regulations make any long term project extremely risky.Based on the abovementioned factors, a graduate course was designed and implemented in order to prepare the students to deal with the main economic issues and challenges faced by the industry. Besides the basics on economic engineering, the course covers advanced material related to budgeting, scheduling and corporate planning.Monte Carlo simulation, economic decision tools, risk analysis for oil industry projects, investment risk and simulation, economic analysis of operations, production forecasts and its associated costs and expected profits are also studied.Furthermore, the students are also required to prepare a project where actual challenges from the industry are analyzed under the perspective of the risks and uncertainties involved. In the project, associated costs and economic results also have to be determined and scrutinized. All projects are presented in a seminar at the end of the course. In addition, a "Newsletter" analyzing current problems, challenges and industry development is produced weekly by the group during the duration of the course.These two tools, the project and the Newsletter, have raised in participants a great deal of interest for economic matters related to each one's individual area of expertise.The paper details the course experience providing examples of main projects developed as well as participants’ feedback.
Design, Engineering, and Construction of Steel Catenary Risers for Indonesia Deepwater Field Applications
Authors: Korloo Jafar , Thomas David 
Published: December 2007

Abstract
Risers play an important role in the drilling, production, and transportation of hydrocarbons and other fluids associated with offshore oil and gas production. For a floating production system, risers provide the link between the surface facility and the subsea flowlines / pipelines that in turn link to the oil/gas wells, and to the on shore storage and export facility.
Risers are one of the most challenging aspects of deepwater projects, and also have a direct influence on the selection and design of both the floating facility and its mooring system.
There are a number of deepwater riser concepts. The most economical solution is typically Steel Catenary Risers (SCR) which are made up of welded rigid pipe sections. The main advantages of SCRs is that the steel pipe has a relatively low cost and there are relatively few other components to consider. However, the construction and long term fatigue performance of the SCRs present significant challenges to the engineer.
The environmental conditions in the deepwater areas of East Kalimantan, Kutei basin can prove suitable for the application of SCR riser concepts. The first application of SCRs in the Kutei basin is on the West Seno Floating Production Unit (FPU). This is also the world's first application of SCRs supported by a barge type floating structure.
This paper presents an overview of the application of SCRs in the Kutei basin with reference to West Seno field experience. The following areas are addressed: Design and engineering;Material selection;Welding issues, qualification of welding procedures and fatigue tests;Construction, inspection, NDE, acceptance criteria;Pre-installation, hook up and as installed configuration verification
Successful Placement of Openhole Plug in HT Conditions
Authors: Araiza Gúmaro Guzmán , Rogers Hank , Peña Lauro , Montoya Salvador 
Published: December 2007

Abstract
This case history paper describes the use of a bottomhole kickoff assembly (BHKA) tool to place openhole plugs in a high-temperature well. The well was a 6 ½-in. diameter borehole with 52° deviation and 174°C (345°F) bottomhole static temperature (BHST). Depth was 5775 m (18,946 ft). Even though these extreme conditions were anticipated, they were discussed with the operator because two earlier attempts to achieve a kickoff had failed.
In this successful kickoff operation, the BHKA was tagged 1 m (3.3 ft) below the calculated top of cement and was tested to 6 tons over the plug, using a 165-mm (6 1/2-in.) roller cone bit. Conditions for both the tool and cement slurry were extreme. Kickoff was successfully accomplished during the first 8 m (26 ft) of the BHKA plug; formation cuttings of 99% were reported.
Flow Assurance Challenges in Deepwater Gas Developments
Authors: Kopps Richard , Venkatesan Rama , Creek Jeff , Montesi Alberto 
Published: December 2007

Abstract
The Flow Assurance strategy is crucial in the early stages of development of subsea gas fields. The key questions in early development are an optimal tradeoff between managing risk effectively while ensuring deliverability and keeping CAPEX within acceptable project economic limits. The Flow Assurance plan addresses the interaction between production chemistry and multiphase flow and the resulting effects on operability, deliverability, and system performance.
This paper focuses on two key aspects of the flow assurance plan for subsea gas developments, the strategies for managing hydrates and the wax deposition. Hydrate management strategy must focus on preventing blockages versus preventing hydrate formation. To this end the engineer must evaluate flow conditions, system geometry, and production profiles, in addition to temperature and pressure conditions. In particular, a realistic water production profile during field life is needed to frame a workable hydrate management strategy. While continuous injection of thermodynamic inhibitor is the traditional solution, thermal management may be deployed effectively for certain fields, resulting in lower CAPEX and OPEX. Operability at restart must also be evaluated, focusing again on preventing blockage rather than preventing hydrate formation.
In several Indonesia deepwater gas developments, as well as elsewhere in Southeast Asia, gas condensate systems have a relatively high amount of wax (&gt;2 w/w%). This high wax content indicates wax problems may occur during production operations. Thermal management may help solve potential deposition problems. The pour point and the wax appearance temperature indicate the potential temperature for stock tank condensate gelation and the highest temperature that the wax typically deposits. These transition temperatures can also be reduced to manageable levels through solution gas content in the produced fluid. For example, typical simulation tools forecast wax deposition with gas condensates, but these deposits are seldom realized.