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In the past-300ft Leg Jack-Up Rig predominantly used to Drill and Complete wells. In depleted phase currently, MH field is witnessing dominantly well work-over / repair scope to sustain production. Seabed inconsistencies caused by pug marks left by previous Jack-Up rigs and sea-bed pipe line network hinder Jack-Ups to approach platform and rework wells. Specificity of Jack-Up Rigs to approach Specific Platforms due to signature pug-marks left behind Increase in market demand for large Jack-Up rigs, increased day rates to very high levels. Above technical and economic compulsions drove decision making and acceptability to consider modular rigs over other alternatives. In order to ensure optimum performance of your rig, reduce downtime and maintain safety of your personnel, planned maintenance and accurate inspections are essential. Drilling's Rig Inspection Workshop (RIW) teaches the inspection and maintenance procedures required to ensure equipment integrity onland rigs, platform rigs and jack-up rigs. Candidates learn to implement the relevant standards and understand industry requirements so that they can verify the condition of a rig's equipment and improve safety, thus reducing the number of accidents and protecting the asset. I.
In the past-300ft Leg Jack-Up Rig predominantly used to Drill and Complete wells. In depleted phase currently, MH field is witnessing dominantly well work-over / repair scope to sustain production. Seabed inconsistencies caused by pug marks left by previous Jack-Up rigs and sea-bed pipe line network hinder Jack-Ups to approach platform and rework wells. Specificity of Jack-Up Rigs to approach Specific Platforms due to signature pug-marks left behind Increase in market demand for large Jack-Up rigs, increased day rates to very high levels. Above technical and economic compulsions drove decision making and acceptability to consider modular rigs over other alternatives. In order to ensure optimum performance of your rig, reduce downtime and maintain safety of your personnel, planned maintenance and accurate inspections are essential. Drilling's Rig Inspection Workshop (RIW) teaches the inspection and maintenance procedures required to ensure equipment integrity onland rigs, platform rigs and jack-up rigs. Candidates learn to implement the relevant standards and understand industry requirements so that they can verify the condition of a rig's equipment and improve safety, thus reducing the number of accidents and protecting the asset. I.
This paper presents a case example to illustrate how a consistent geomechanical approach and coherent data integration are used to provide the basis for the evaluation of formation mechanical properties, characterization of in-situ stresses, identification of wellbore failure mechanisms, and calibration of a wellbore stability model. The calibrated model is then used in conjunction with the proposed build-and-hold and catenary well profiles to generate the mud weight windows for an ERD well. To provide further insight into the wellbore stability with respect to wellbore trajectories and in-situ stresses, contour plots of mud weights are generated for a critical depth interval. These contour plots delineate potential instability areas and are critical for predrilled well trajectory designs. Additionally, an innovative approach to establish the lower limit of mud weight for wells that cannot be drilled without failure zones (breakouts) forming around the wellbore is presented. This approach enables difficult wells to be drilled, with the lower mud weight reducing the risk of formation damage and increasing the rate of penetration. Introduction Resak Field, located offshore of Peninsula Malaysia, is operated by PETRONAS Carigali Sdn. Bhd. (PCSB). The field is currently under development and 13 wells will be drilled radially from a production platform in a ‘bow-tie’ pattern. In order to cost effectively drain the proven reserves without having to add a lightweight structure and pipelines connecting to the processing platform, some of the development wells will be drilled extended-reach. Resak LOC-11 is an extended-reach well designed to drain the southeastern portion of the field reserves. Two wellbore trajectories, build-and hold and catenary, were proposed. Fig. 1 and Fig. 2 show the schematics for the two well plans. Extended-reach drilling (ERD) can be extremely costly if not optimally designed. Occurrences of borehole instability-related problems, such as stuck pipes, fishing and sidetracking operations, have been reported to increase with increasing wellbore inclinations1 and extended-reach drillings. In addition to escalating costs, wellbore instability can also result in poor hole conditions, which ultimately would affect the quality of reservoir characterization and the effectiveness of primary cementing. Poor primary cementing in high angle gas wells is of particular concern because of possible gas migration during cement setting. Faced with the challenges of delivering the well within AFE, the Resak project team decided to conduct the wellbore stability assessment for the proposed ERD well. The results of the geomechanical analysis will be used to:decide which wellbore trajectory, andestablish the mud weight program that will mitigate wellbore instability and improve operational performance. An extensive in-house database is available through comprehensive data acquisition programs during the exploration and appraisal phases. Due to the data quality of older wells, only the most recent appraisal well data (Resak 6F-18.4) was selected to provide the basis for rock mechanical properties and in-situ stress characterizations as well as wellbore stability model calibrations. The calibrated model was then used in conjunction with LOC-11's well plans (hole deviations and azimuths) to generate the stable mud weight profiles. The safe operating mud weight window can then be implemented together with good oilfield drilling practices to mitigate potential borehole instability-related problems. The purpose of this paper is to present a consistent geomechanical approach for developing the optimal mud weight program for LOC-11 ERD.
fax 01-972-952-9435. AbstractWith the emergence of rotary steerable systems, the technical issue concerning the bit design for a specific directional application has reappeared. Today, a bit must be specifically designed for use with a particular directional system : rotary bottom hole assembly (BHA), steerable mud motor or rotary steerable system (RSS). The reason is that the bit must have the ability to respond properly and rapidly to a side force applied by the steering system in order to initiate a deviation as requested. To do so, the bit must have a predetermined steerability compatible with the directional system in order to provide the optimum dog leg potential.The new generation of directional drilling systems differentiates "pointing the bit" from "pushing the bit". As a consequence, the bit directional response is a key factor that operators and directional drillers need to know to make the good adaptation between the bit and the BHA. However at the moment, there is no standard method that can propose a way to classify bits according to their steerability and walking tendency.Based on a comprehensive analysis of the directional behavior of polycrystalline diamond compact (PDC) bits (numerical simulation, pilot and field tests), a simple methodology has been developed in order to define and evaluate the steerability and the walking tendency of PDC bits. This methodology is used to classify the PDC bits defined with their IADC bit profile codes.As the PDC bit steerability is mainly a function of the bit profile, the gage cutters and the gage pad, some design recommendations are given concerning these three parts. For each IADC bit profile code, the bit steerability and the walking tendency is estimated through some formulas linking only the heights and lengths of the cutting profile. Some guidelines are also given about the gage pad length and gage cutters characteristics in order to achieve improved steerability.This simple method based on geometrical criteria enables to estimate quickly not only the PDC bit steerability, but also the maximum dog leg potential achievable by the PDC bit, when coupled with the steering system.
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