bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unusual Carbonate Rocks Showing Increasing Trends for Rock Compressibility as the Applied Net Stress Increases
Authors: Sadeghazad Ayoub , Beiranvand Bijan 
Published: December 2007

Abstract
Pore volume compressibility is a major energy source for the naturally depleting reservoirs. A good estimate of pore volume compressibility is necessary for proper simulation of dynamic reservoir modeling. Therefore, a detailed study and investigation must be done to understand and quantify the rock compressibility influencing parameters.
The main objective of this paper is to evaluate and discuss the influence of geological and petrophysical parameters such as rock texture, grain fabric, porosity type, grain density, and pore size distribution on the pore volume compressibility.
Compact tests using CMS-300 equipment and pore volume compressibility tests were performed on more than 100 core plugs taking from upper Cenomanian Sarvak formation (equivalent to Mishrif formation). This formation is mainly a non-vuggy and non-fractured carbonate reservoir rock. The tests have been carried out under several net stresses during increasing and decreasing stress cycles. The calculated compressibility data mainly follow the major trends including: steadily decreasing, sharply decreasing followed by constant line, and increasing trend.
Obviously, the compressibilities following the increasing trend line, which is the unusual case, is the most interesting part of this discussion. In addition, other techniques and experiments such as mercury injection, SEM, rock type evaluation, gamma ray log, and natural gamma ray spectroscopy method have been applied on some of the samples, especially on samples with unusual trends, to understand the mechanism in which show unusual compressibility trends.
Advances in Horizontal Oriented Perforating Optimize Perforating and Production While Maintaining Borehole Stability
Authors: Benavides Simon P. , Myers William D. , Van Sickle Edgar W. , Vargervik Kristian 
Published: December 2007

Abstract
Perforating in highly deviated or horizontal wells presents any service company with a serious technical challenge. Attempting to maintain wellbore and perforation tunnel stability by perforating in the direction of maximum stress compounds the complexity of the perforating job. Ensuring that orientation remains valid while navigating through severe doglegs requires detailed pre-job design planning supported by applicable research data.
This paper discusses advances in horizontal oriented perforating in long horizontal sections designed to optimize perforation efficiency and production. The techniques and results discussed are applicable to any horizontal or highly deviated well where orientation of charges to maintain wellbore stability is critical. New developments to navigate through severe doglegs and maintain orientation are significant contributions to perforation technology. Some of the results and experiences encountered while performing an oriented perforating job in a 2246-m horizontal section of a well in the North Sea for a major operator are also discussed in this paper. A world record was set by perforating a total of 1496 m of the horizontal section in a single trip with orientation successfully verified. Additional discussion on the testing and research that preceded the job is presented.
As demonstrated in positive results from the North Sea case history, perforating with oriented charges in horizontal sections will play a key role in the future to assist operators increase and optimize production from new or declining fields.
An Alternative Wellbore Stabilisation and Sand Control Technology – Application of Expandable Sand Control System in Ulti-lateral Wells
Authors: Wang J. L. , Ren G. , Aitken S. , Yuan M. 
Published: December 2007

Abstract
The Xijiang field lies offshore China in the South China Sea and is operated by Phillips China Inc. The reservoir is unconsolidated and requires sand-control, however conventional sand-control techniques are complex when applied to multi-lateral well completions. The expandable sand control system offers an alternative, which combines a larger final wellbore diameter and zonal isolation whilst being simpler to install in multi-lateral well completions.
The field is, now mature and water-cuts have increased, making the use of horizontal well technology attractive in order to enhance the production rate, minimize drawdown and maximise the recovery by deferring water coning. Furthermore, the limited remaining reserves and drilling slot constraints meant that multi-lateral wells were the most attractive option for further development of the remaining reserves and improving ultimate recovery.
This paper discusses how due to the nature of the wells, the requirement for wellbore stabilization and zonal isolation resulted in the selection of Expandable Sand Control technology to complete the reservoir.
In this case study multi-lateral well, the main bore is a three zone lateral with a total of 299m Expandable Sand Screen (ESS) across the target reservoir and 69.5m Expandable Isolation Sleeve (EIS) across water-bearing sands and shale. The top zone is a cased hole completion and the lower two zones are open hole completions. The other lateral branch has 930m of 7" liner running inside the horizontal open hole followed by 347.5m ESS. The installation of this sand control completion combined with multi-lateral technology is then detailed and the lessons learned discussed.
Finally, the post-production well performance data is compared and contrasted with previous wells to demonstrate the improvement in productivity achieved with this new method for wellbore stabilisation of the horizontal wells in poorly consolidated reservoirs. Initial production data shows the well to produce 6,900bpd oil with only 5% water cut which is 2-3 times more than the previous wells completed with traditional sand control methods at the same production drawdown.
Addressing Common Drilling Challenges Using Solid Expandable Tubular Technology
Authors: Andrews Stacey , Keel Doug 
Published: December 2007

Abstract
Maximizing hole conservation while optimizing well economics in both conventional and deepwater wells is a continual challenge. Solid expandable tubular systems address this challenge and others by applying technology that provides significant solutions.
Solid expandable tubular systems have been installed in both openhole and cased-hole wellbores since November 1999. These installations occurred in a variety of well environments on land, offshore, and in deepwater to solve a myriad of drilling and completion challenges.
This paper will discuss case histories in depth by describing drilling challenges surrounding the use of solid expandable tubular technology and the conditions leading to the use of this technology.
New Setting Technique for Gravel Pack Packers Increases Operational Safety and Reduces Costs
Authors: Dawson Mark E. P. , Smith Marshall N. 
Published: December 2007

Abstract
In the typical life cycle of a given well, the majority of the budget is generally allocated to the drilling phase with the remainder to cover the completion costs. If, however, these stages are not kept within planned budget and time parameters, it becomes critical to reduce the time and cost in the final completion strategies to enable the budgeting of the project to be successful. This paper will discuss a new method for setting a gravel-pack packer that can assist in reducing the overall time associated with the completion phase of a well bore, and in turn, the subsequent cost.
Packers are traditionally set by dropping a setting ball into the workstring to create a plug in the service tool that is either pinned or threaded to the gravel-pack packer. The plug is subjected to an applied pressure that is translated from the service tool to the packer, which both begins and finishes the packer setting process. The creation of this plug, ball on seat, is affected by several factors. Such factors are wellbore geometry and deviation, the type of completion fluid, and the packer setting depth. Each of these factors relates directly to the time needed to create the plug, the ball landing on seat, and in certain instances, the time needed to reverse the setting ball out of the work string. Again, the time to drop and/or reverse the setting ball all affect operational times.
The new technology available eliminates the time and risk associated with using setting balls against which pressure is traditionally applied to set gravel-pack packers. As the system is hydrostatically driven, it allows a constant hydrostatic pressure to be maintained on the formation, reducing the risk of formation collapse, surges on the formation seen when shearing the ball seat out, and the risk of the ball seat shearing prematurely. With fewer completion operations, chances for misruns are reduced, and safety and environmental risks are minimized. The reduction in setting time allows this system to be considered a viable and affordable option for wells that meet the necessary criteria. The cost savings are even greater in offshore environments.
Intelligent Drill Pipe Creates the Drilling Network
Authors: Jellison Michael J. , Prideco Grant , Hall David R. 
Published: December 2007

Abstract
Drill pipe capable of transmitting high-bandwidth downhole data and surface control signals has been developed and successfully tested. The system incorporates a high-speed data cable protected in a high-pressure conduit that runs the length of the joint. The cable terminates at induction coils that are installed in protecting grooves machined in the secondary torque shoulders of double-shoulder tool joints at each end of the pipe. The system is virtually transparent to standard rig procedures and offers robust, reliable operation.
The new system has successfully demonstrated error-free, data transmission rates of up to 2,000,000 bits/sec. The bi-directional system can transmit real time MWD/LWD data, as well as, send commands or signals from the surface to operate downhole tools and sensors. Full-length prototype joints have been used extensively to drill and transmit data in test wells. Results of these tests, along with plans for field-testing in actual drilling environments, are presented.
Potential drilling enhancements include improved bit life, optimized casing point selection, enhanced kick detection and control, and elimination of wireline log runs and survey time to retrieve MWD/LWD data. Telemetry drill pipe can expand the potential for Underbalanced Drilling (UBD) techniques and improve the safety of UBD operations. The paper presents overviews of new concepts and technologies that can take advantage of the high-bandwidth, two-way communication capabilities of the system. Seismic-While-Drilling with the ability to look ahead of the bit, enhanced well control systems with sensors distributed along the drill string and drill string dynamics monitoring systems represent areas for innovation with the telemetry drill pipe.
Telemetry drill pipe can improve well and field productivity by providing more complete, real-time logging information and reduce drilling time and costs and enhance well control by providing real-time downhole drilling data and early kick detection.
Under-Balanced Drilling Experience in a Shallow Clastic Oil Field, Offshore Sabah, South China Sea
Authors: Bourgeois Gilles David , Chu Joanne , Terwogt Jan Hendrik , Mahran Awang Kasumajaya , Wisnugroho Alberthnego 
Published: December 2007

Abstract
Following encouraging results of Under-Balanced Drilling ("UBD") applications in the North Sea and onshore Canada, Shell Malaysia Exploration and Production ("SM-EP") embarked upon the application of this technology in a shallow clastic oil field in offshore Sabah. Relatively little information is available in the public domain regarding the effectiveness of UBD in clastic oil reservoirs. This paper provides factual evidence relevant to the assessment of UBD-induced added value. The paper also provides a comparison between the cost and benefit of UBD with that of Under-Balanced Perforating ("UBP") in a two-well trial.
Every pressure regime, reservoir fluid type, geological circumstance, etc, requires a specific operational configuration custom made for the situation at hand. This is a major source of UBD-induced incremental cost. Different reservoirs require different UBD configurations so analogies that assist the business case of a UBD project are currently limited and are difficult to find. This was the first offshore application of crude oil and hydrocarbon gas injection as drilling fluid in jointed pipe operations. A description of the incentives and risks of our specific geological circumstances is provided. Detail will be provided regarding our UBD design, main operational-risk mitigation measures, and the strategy used to appraise the added value of UBD. The complexities, incentives, and pitfalls of our UBD strategy will be chronicled. The initial results of this first-ever UBD trial within SM_EP will be published, along with the lessons that we have learned.
Pushing the Limit with Coiled Tubing Perforating
Authors: Acorda Edgar Paul R. , Engel Stephen P. , Chu Joanne L. J. 
Published: December 2007

Abstract
The use of coiled tubing in the oil and gas industry has become wide and varied since its inception some forty years ago. From its early applications of sand clean out and unloading wells, coiled tubing is also now frequently used to convey perforating guns. With the trend of new wells drilled to a more complex trajectory and with horizontal sections becoming longer and longer, perforating with e-line has become difficult, if not impossible. With the added benefit of underbalanced conditions, extreme lengths and weights of guns to perforate extensive intervals in a single run, coiled tubing has evolved into an invaluable tool.
This paper presents a case history where 2" coiled tubing was used to successfully convey some 2,900 ft of guns having a BHA weight in the order of 14 ½ tons. The trend of ever increasing BHA weights is extending the operating envelope and creating new records of longest and heaviest coiled tubing deployed perforating. Meticulous engineering and pre-job planning is a prerequisite for deploying these types of assemblies. Job simulation and operational data are presented to highlight the reliability of computer models in predicting the proximity of what can and cannot be achieved. Great focus is placed on tools and techniques that have been employed to reduce the friction in the BHA and coil. The paper also discusses the risk assessment and mitigation plans of pushing the technology to such limits.
Fit-for-Purpose Technologies Applications in Commercialising a Marginal Oil Field
Authors: Musa Mohd Bahrulnizam , Wai Foo Kok , Kheng Looi Lai 
Published: December 2007

Abstract
Alab is an oil field offshore Sabah, east Malaysia. It is about four kilometres from nearby offshore facilities and its water depth is 48 metres. With limited data from the only discovery well and a marginal STOIIP, it definitely required unconventional approach to commercialise the resource.
Among the possible development options, extended reach drilling (ERD) from the nearby facilities was chosen. The other options were satellite platform and subsea wellhead developments. Both are to be tied back to the nearby facilities. ERD technology was opted for its low CAPEX and early oil production due to ullage availability at the host facilities.
The marginal resource means little room for error, yet there are many uncertainties associated with the limited data. Reservoir simulation technology was used to assess the geological and operational uncertainties and risks. The reservoir simulation study results was used to firm up the reservoir development plan and to prepare risks mitigation plan. Using a structured analysis approach, the drilling uncertainties and risks are included in the probabilistically estimated wells’ duration and cost. In the way, the drilling uncertainties and risks are incorporated into the wells’ AFE.
In drilling the ERD wells, rotary steerable bottomhole assembly technology was used to drill the difficult turn-and-drop profile in production sections where normal mud motor is unable to overcome high sliding drag. To ensure good well production performance and to prevent the unconsolidated sand production, expandable sand screen technology was selected over gravel pack due to near horizontal well trajectories. The well trajectories have also made periodic reservoir monitoring such as PBU requires expensive CTU jobs. A bottomhole permanent gauge was installed in one of the ERD wells for the purpose, as it is more economics.
This paper is concluded with the benefits and value creations of the mentioned fit-for-purpose technologies.
Marginal Oil Developed in a BIG Way – A Case Study of the Development of Oil Reserves in the Pattani Basin
Authors: Schut Gerard , Kaweeyanun Pairoj , Duke Matthew , Samingkaew Kowit , Maroongroge Vichai 
Published: December 2007

Abstract
This paper describes how oil is being developed from small compartmentalized fluviatile reservoirs, stacked vertically from around 4000’ to 9000’ below sea level. The oil reservoirs are encountered intermittently amongst gas reservoirs. The oil and gas reserves are being developed through low cost wells and platforms that are installed and brought on production in a back-to-back manner in order to maintain the oil rate at the facility capacity of a new oil processing platform.
The paper provides some historical background and explains the challenges that were faced in bringing this project to fruition. Initially, the oil was considered a problem within the context of an existing and established gas infrastructure. Given the limited size of the oil reservoirs and the incompatibility of oil in the gas systems, an innovative development plan was required, that would enable sufficient economies of scale to reach economic viability.
A focussed team was formed to review options to develop the oil-rich gas prospects that were geographically spread over an area of around 250 km2. The oil development scheme that was chosen requires the back-to-back installation of over 10 wellhead platforms and drilling of over 105 wells. The oil is transported through 3-phase pipelines to a new oil-processing platform, from which oil is exported to a new export system and an FSO and gas is transferred to the existing gas infrastructure. Development costs are balanced against reservoir recovery using "fit for purpose" solutions to make the project economically viable. The paper describes the full development scheme, ranging from well design (spacing, drilling, formation evaluation, completion) through oil processing to oil export/storage, and explains which "fit for purpose" solutions were applied.
The project was fast-tracked, and risk management was applied to deal with the uncertainties in oil reserves/recovery and cost exposure associated with the oil development. From drilling the exploration wells to "first oil" production took only 19 months. The paper also reviews several factors that contributed to the ability to fast track and manage the risks of the project.
E8 Innovative Field Development
Authors: Bos Aat , Hamdan Idawati , Voon Chin Hon , Singh Updesh 
Published: December 2007

Abstract
E8 is a carbonate reservoir with an estimated ultimate recovery of 2.157 Tscf gas and 35 million stb of condensate. The reservoir is a carbonate build-up, consisting of two pinnacles connected through a saddle area. The field will be developed at a peak capacity of 600 MMscf/d. As a result of the study work for the FDP, the expectation recovery has increased by 370 Bscf gas. This is driven by an updated structural model based on a revised seismic interpretation. This has been achieved through a combination of improved depth conversion method (Depth Team Express) as well as uncertainty reduction based on seismic inversion techniques.
In the era of uncertain hydrocarbon prices, optimisation is aimed at ensuring high system availability, maintaining safety and environmental standards while achieving an economic development. This paper describes the efforts undertaken to maximise recovery from the field and the initiatives undertaken to resolve challenges. The main challenges faced in converting the development concept from standalone to satellite were production forecasting, security of supply, slug management and unmanned operations.
Merging "People" And Technology – A Case Study
Authors: Deka Mousumi 
Published: December 2007

Abstract
Oil India Limited is a premier Public Sector E&P petroleum company having major operational areas in the remote North-Eastern part of India with more than hundred years of experience in the business.
With the change in the economic environment and globalisation of Indian economy, it has become imperative for Oil India Limited to take advantage of new technology and merge it with existing culture and legacy seamlessly. Adoption of new tools in Information Technology for decision support and knowledge management has been the need of the hour.
To achieve the objective, a tailor made approach targeted towards ‘user traits’ was adopted. IT professionals worked closely with the professionals of different disciplines and, thereby, got the detailed insight into the mindset, functioning and procedures of various functions of the company. The ‘merger of minds’ of IT professionals with other core functions increased the acceptability of IT solutions at all levels.
This paper describes various methodologies Oil India Ltd. has adopted to introduce computerised crude oil reconciliation and special efforts channelised towards "people acceptance" of the new tools in lieu of largely manual system hitherto being followed in the company.
Competency, Development, and Training: Tools for Building Engineers of the Future
Authors: Suryodipuro Hudi D. , Thomas Bruce D. 
Published: December 2007

Abstract
How adequately are engineers prepared to meet the challenges of the industry today, using various tools such as competencies, development programs, and state-of-the-art training techniques?
This paper will describe a global development and competency framework for technical personnel that both describes and tracks job competencies to the task level, with respect workflow processes, through the three points below:
Utilizing blended learning techniques (combination of instructor-led activity, online training, simulations, seminars, and university programs) will provide the means of developing knowledge. By participating in development programs, engineers will work under a mentor to learn the application of a particular role, of skills and of behaviors that are associated with the role. The competency process, as the gateway, will be used to assess and ensure that all knowledge, skills, and behavior are sufficient to perform tasks in accordance with company standards.