The relationships between oil based drilling fluid composition and the associated vapours have been quantified. This information will provide drilling Operators with improved control in the working environments. The study documents the long and short term changes in base oil selection and fluid compositions. The study is based on the generation and assessment of data collected from the vapour emissions of oil based drilling fluids with varying compositions and at a range of temperatures. Mineral oil based drilling fluid samples from the field have been investigated and compared to laboratory samples of similar basic composition. The impacts of other components in the drilling fluid formulations are also discussed. The purpose of the study was to enable a better understanding of the potential working environment hazards when using mineral oil based drilling fluids. One result of this understanding is that new rig construction designs, and older rig upgrades can be more informatively performed. Consequently this will reduce the repetition of continual modification costs.
Numerous performance enhancement initiatives were used by the operator for the Sakhalin I project in drilling and completing the world-class extended reach drilling (ERD) program at the Odoptu Field, Sakhalin Island, Russia. As a result of the drilling successes and favorable production performance, the initial seven-well ERD program was expanded to nine wells, including the world record OP-11 well. The operator's philosophy of relentless redesign to remove limiters from the drilling process resulted in significant performance improvements in all areas of drilling and completion operations. This paper provides details and results for many of the key performance initiatives used.Operators are continually striving to drill longer, faster, and at lower costs while minimizing risks to provide maximum shareholder value. During the Odoptu ERD drilling program, a constant progression of performance improvement, time reduction, and dependability strategies were used. These optimization initiatives resulted in significant performance improvements for the project and numerous industry records.The nine Odoptu ERD wells were drilled at a cost below the budgeted amount for the first seven wells. As a result of the initiatives employed, non-productive time (NPT) was reduced from an average of 21% on the first four wells to less than 3% on the last five. Aggressive shock and vibration mitigation efforts through bit redesign, bottomhole assembly (BHA) vibration analysis and operational optimizations resulted in record BHA runs. Wellbore instability issues were successfully mitigated through design and operational practices. Completion practices were high-graded and optimized and as a result, all completions in the long horizontal intervals were successfully placed using partial string rotation techniques.Drilling ERD wells at the edge of industry experience in a cost effective and low-risk manner requires careful attention to detail and a commitment by the operator and contractors to continuously improve.
The development of methods to characterize the relative vibration tendency of alternative bottomhole assemblies (BHA) has enabled deliberate tool redesign to reduce vibrations. To achieve the greatest benefit, tool redesign is most effective if applied early in the tool design cycle where important configuration parameters are most easily adjusted. This paper outlines several design issues that need to be resolved so the future generations of tools have inherently lower vibration levels.The use of multiple special-purpose tools (such as logging tools, rotary steerable assemblies, and ream-while-drilling tools) generates significant constraints on BHA configuration options. A redesign methodology to achieve lower vibration indices can be used to investigate modified components, dimensions, and configurations to select the best BHA configuration for specific drilling operating conditions.Case studies are used to investigate BHA designs with flex stabilizers above rotary steerable tools. The flex stabilizer comprises a stabilizer with a smaller diameter connecting flex sub to facilitate rotary steerable directional objectives. It is typically wired for tool signals and is frequently run by vendors. In another case study, the spacing below a reamer is evaluated and drilling data is compared to other assemblies in the same formation. In this example, the spacer provides an increase in the distance between contact points to allow both the stabilizer and reamer to seek the centerline with less interference. The fourth case study evaluates changing contact locations in the BHA by swapping the order of logging tools resulting in different borehole contact positions. Finally, a theoretical study illustrates how changing BHA components and dimensions affect the model vibration indices.The operator has field experience with BHA redesign that has directly led to significant improvement in drilling performance. The benefits include higher rate of penetration (ROP), longer time on bottom, less wear of drilling tool components, and reduced frequency of trips.
Summary The development of modeling methods to characterize the relative vibration tendency of alternative bottomhole assemblies (BHAs) has enabled deliberate tool redesign to reduce vibrations. To achieve the greatest benefit, tool redesign is most effective if applied early in the tool-design cycle in which important configuration parameters are most easily adjusted. This paper outlines several design issues to resolve so that future generations of tools have inherently lower vibration levels. The use of multiple special-purpose tools [such as logging tools, rotary-steerable assemblies, and ream-while-drilling (RWD) tools] generates significant constraints on BHA-configuration options. A redesign methodology to achieve lower vibration indices can be used to investigate modified components, dimensions, and configurations to select the best BHA configuration for specific drilling-operating conditions. Case studies are used to investigate BHA designs with flex stabilizers above rotary-steerable tools. The flex stabilizer is composed of a stabilizer with a smaller-diameter connecting flex sub to facilitate rotary-steerable directional objectives. It is typically wired for tool signals and is frequently run by vendors. In one case study, the spacing below a reamer is evaluated, and drilling data are compared with other assemblies in the same formation. In this example, the spacer provides an increase in the distance between contact points, to allow both the stabilizer and the reamer to seek the centerline with less interference. Another case study evaluates changing contact locations in the BHA by swapping the order of logging tools, resulting in different borehole-contact positions. Finally, a theoretical modeling study illustrates how changing BHA components and dimensions affects the vibration indices. The operator has field experience with BHA redesign that has directly led to significant improvement in drilling performance. The benefits include a higher rate of penetration (ROP), a longer time on the bottom, less wear of drilling-tool components, and a reduced frequency of trips.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractPhillips Petroleum Company Norway has made significant HSE improvements to gain "best in class" results. An industry leadership position has enabled Phillips Petroleum Company Norway (PPCoN) to involve the Norwegian authorities, research institutes, operators, and contractors towards the further development and application of the methods used. An additional benefit of these improvements has been reduced costs of drilling operations. This paper discusses the HSE improvements achieved by PPCoN drilling department and the manner inwhich external organisations have been involved. The paper also identifies the benefits to PPCoN and the external organisations, and how industry-wide improvements have resulted.
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