The Experts below are selected from a list of 297 Experts worldwide ranked by ideXlab platform
Liew Huey Cherng - One of the best experts on this subject based on the ideXlab platform.
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proceedings indonesian petroleum association thirtieth annual convention exhibition august 2005 nine inch x 10 000 psi wp dual conductor sharing Wellheads application on an offshore gas field development
2011Co-Authors: Jean-baptiste Pierre Faget, Jean-christophe Monneyron, Nicolas Payer, Alain Bourgeois, Liew Huey CherngAbstract:Splitter Wellheads allow several wells to be drilled from the same conductor pipe, which can bring significant benefits for conventional offshore developments by reducing the size and/or number of wellhead platforms or by giving access to additional reserves from existing platform slots.
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Nine Inch x 10,000 PSI WP Dual Conductor Sharing Wellheads Application on an Offshore Gas Field Development
2005Co-Authors: Jean-baptiste Pierre Faget, Jean-christophe Monneyron, Nicolas Payer, Alain Bourgeois, Liew Huey CherngAbstract:Splitter Wellheads allow several wells to be drilled from the same conductor pipe, which can bring significant benefits for conventional offshore developments by reducing the size and/or number of wellhead platforms or by giving access to additional reserves from existing platform slots. In April 2003, Cameron dual 9” CSW were successfully installed by Total E&P Indonesie on Peciko offshore gas field development as the first worldwide application of a 9” x 10,000 psi dual splitter wellhead and 4-1/2” x 6,500 psi Xmas-Tree. Thanks to this technology, 120 million USD could be saved on surface facilities by reducing the number of wellhead platforms from 10 to 7 while targeting the same gas reserves. Drilling and completion costs remained in line with initial plans, as the savings made with the slimmed down well architectures were counterbalanced by the higher well departures induced by the reduced number of platforms. To the end of 2004, 16 splitter wells (8 sets of dual CSW) have been drilled and completed without any major technical problem, 14 of them ahead of planning and below budget.
Jean-baptiste Pierre Faget - One of the best experts on this subject based on the ideXlab platform.
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proceedings indonesian petroleum association thirtieth annual convention exhibition august 2005 nine inch x 10 000 psi wp dual conductor sharing Wellheads application on an offshore gas field development
2011Co-Authors: Jean-baptiste Pierre Faget, Jean-christophe Monneyron, Nicolas Payer, Alain Bourgeois, Liew Huey CherngAbstract:Splitter Wellheads allow several wells to be drilled from the same conductor pipe, which can bring significant benefits for conventional offshore developments by reducing the size and/or number of wellhead platforms or by giving access to additional reserves from existing platform slots.
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Nine Inch x 10,000 PSI WP Dual Conductor Sharing Wellheads Application on an Offshore Gas Field Development
2005Co-Authors: Jean-baptiste Pierre Faget, Jean-christophe Monneyron, Nicolas Payer, Alain Bourgeois, Liew Huey CherngAbstract:Splitter Wellheads allow several wells to be drilled from the same conductor pipe, which can bring significant benefits for conventional offshore developments by reducing the size and/or number of wellhead platforms or by giving access to additional reserves from existing platform slots. In April 2003, Cameron dual 9” CSW were successfully installed by Total E&P Indonesie on Peciko offshore gas field development as the first worldwide application of a 9” x 10,000 psi dual splitter wellhead and 4-1/2” x 6,500 psi Xmas-Tree. Thanks to this technology, 120 million USD could be saved on surface facilities by reducing the number of wellhead platforms from 10 to 7 while targeting the same gas reserves. Drilling and completion costs remained in line with initial plans, as the savings made with the slimmed down well architectures were counterbalanced by the higher well departures induced by the reduced number of platforms. To the end of 2004, 16 splitter wells (8 sets of dual CSW) have been drilled and completed without any major technical problem, 14 of them ahead of planning and below budget.
Guttorm Grytoyr - One of the best experts on this subject based on the ideXlab platform.
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Analysis Approach for Estimating Wellhead Fatigue
Volume 3: Structures Safety and Reliability, 2018Co-Authors: Kristoffer H. Aronsen, Sergey Kuzmichev, Kathrine Gregersen, Guttorm Grytoyr, Finn Kirkemo, Lorents ReinåsAbstract:A structured technology development process targeting to combine industry and Statoil’s experience has produced an engineering approach for wellhead fatigue analysis that is verified against measurements of load and load effects in actual subsea wells. This paper outlines Statoil’s wellhead fatigue analysis approach, which is based on the new industry standard for wellhead fatigue analyses, DNVGL-RP-E104, ref. [1]. Parts of the methodology has been presented in previous papers. The present paper provides a birds eye view, putting all the pieces together into one coherent methodology. The development and validation of an engineering approach for estimating the bending moment in the surface casing, between the wellhead housing and top of cement, will be presented in detail; this has previously been referred to as load sharing between wellhead and conductor. The wellhead fatigue analysis approach is based on a “coupled model”, which in this case means that the conductor with PY-soil springs are included in the model, compatible with industry recommendations [1], with the following main characteristics: • The lower boundary condition is modelled as a conductor in soil with a bending stiffness equivalent of the well system. • Soil and template interaction is modelled by discrete springs. • The global riser load analysis is run with long crested waves and head sea. Directionality of the waves are handled by reduction factors applied to the damage rate. Alternatively, directionality effects may be included by running multiple wave directions with short crested waves. • Fatigue capacity of the hotspots in the well system is represented by ΔM-N curves generated from detailed FE models. Typically, ΔM-N curves are established for connectors, welds between housings and casings, and for the wellhead housings. The paper includes validation against full scale measurements for a wellhead of preloaded type. In addition, it is demonstrated how the approach can be used for Wellheads where the high-pressure housing may rotate inside the low-pressure housing. For this case, the validation is performed against a full 3D solid element model. The analysis approach presented is computationally effective and it will hence enable increased focus on sensitivity analyses. Analysis work is moved from time consuming local- and global analysis, to effective post-processing of data. Uncertainty in the input parameters has been found to significantly influence the fatigue estimate. Understanding these effects is considered vital for making conscious decisions on the fatigue life of a well. See e.g. [8], [10] and [20]. As pointed out already in 1985 by Valka et.al., ref. [5], and also by Milberger et. al., ref. [6], the cement level, and the relative motion of the two housings, represent large uncertainties. Macke et. al, ref. [10], showed that the additional uncertainty due to cement level and friction between housings exceeds the levels covered by the traditional fatigue safety factor of DFF = 10. A method is proposed to handle this in a consistent manner.
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Fatigue Capacity of Wellhead Housings
Volume 3B: Structures Safety and Reliability, 2017Co-Authors: Sergey Kuzmichev, Kristoffer H. Aronsen, Javier Rodriguez Garcia, Guttorm Grytoyr, Finn Kirkemo, Erik SimonsenAbstract:The issue of wellhead fatigue has been given significant attention during recent years. The complexity of the wellhead system in terms of interactions betwe[en conductor (low pressure) and wellhead (high pressure) housings leads to various analysis methods being proposed to evaluate fatigue damage in the system. Most of the critical base material hotspots are located in the wellhead housing region where the loads start to distribute between the high- and low pressure housing and the load paths are highly complex varying for different input parameters. Due to this, detailed fatigue analyses are typically performed on a project to project basis for the same wellhead geometry. This paper proposes an approach that simplifies the analysis of the base material hotspots in the housings and makes it independent of where the specific type of the wellhead system is used. It is suggested to consider the housings of the wellhead system as one component with a single characteristic M-N curve, or a few M-N curves if complexity requires so. The M-N curve is a specialization of the standard S-N curves provided in rules and standards. They are generated by combining the calculated load-to-stress curve at a given hotspot with the applicable S-N curve. The load used as a reference is typically a cross-sectional moment at the top of high pressure housing. For these purposes 3D FE models have been developed for two principal wellhead types, rigid lock and non-rigid lock. The models are used to investigate the effect of different boundary conditions and applied loading on M-N curves for each hotspot analysed. Sensitivity studies have been performed for several parameters that are considered important in wellhead fatigue analysis. Based on the sensitivity studies, the effect of each parameter on typical base material hotspots is presented. This paper provides estimates for the spread in the M-N curves for each individual base material hotspot in the wellhead housings. Results indicate that a single characteristic M-N curve per wellhead system type can be selected to represent the wellhead housings. In addition, based on results from the analyses carried out, recommendations regarding generalized boundary conditions to obtain a characteristic M-N curve for a specific wellhead type have been given.
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Comprehensive Instrumentation of Two Offshore Rigs for Wellhead Fatigue Monitoring
Volume 3B: Structures Safety and Reliability, 2017Co-Authors: Svein Herman Nilsen, Massimiliano Russo, Guttorm GrytoyrAbstract:Over the last decades, the complexity and duration of offshore drilling operations have steadily increased. The size and weight of the risers and BOP stack has grown significantly. These factors have led to an increase in fatigue loads imposed on the wellhead structures during drilling and completion operations. Wellhead fatigue might ultimately lead to loss of well structural integrity and pressure containment and therefore safe and reliable drilling of subsea Wellheads has gained high priority in the global oil and gas industry. This paper presents two of the most complex real time instrumentation campaigns for drilling operations. Analyses of a connected drilling riser system including the well structure are complex and involve several engineering disciplines. In addition, there are many unknowns going into the equations when accumulated fatigue damage of the wellhead is estimated. Therefore, assumptions need to be made, very often on the conservative side. A typical example are the global drilling riser analyses where the environmental conditions, actual rig motion and riser / BOP behavior are uncertain. With the duplex scope of accurately documenting the wellhead fatigue status during drilling operations and of achieving a better understanding of the actual risk level of wellhead fatigue, Statoil decided to start a very comprehensive monitoring campaign. Two MODU representing very different generations of rigs in terms of weights and types of equipment were instrumented from topside to BOP connector. Strain gauges were installed around the BOP connector as close as possible to the wellhead in order to capture wellhead response as accurately as possible. Due to the large number of sensors, high accuracy requirement and high sampling frequency of data to be shown live, a cabled solution was selected vs remote battery operated sensors transmitting via acoustic. Double set of cables, sensors and topside equipment were installed in order to make the instrumentation system fully redundant and suited for permanent installation. All data were additionally made available real time onshore to allow the full overview of the operation. To author’s knowledge, these two instrumentation systems are the most comprehensive and complex of this type installed on a drilling riser as of today. The first of the two system was installed approximately three years ago and it is still in operation. This paper describes the instrumentation systems installed and gives an extract of the quality data extracted and already used in already published studies [1, 2, 3].
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Wellhead Fatigue Damage Based on Indirect Measurements
Volume 5B: Pipeline and Riser Technology, 2015Co-Authors: Guttorm Grytoyr, Fredy Coral, Halvor Borgen Lindstad, Massimiliano RussoAbstract:Enabling safe and reliable operations of subsea Wellheads has a high priority in the global oil and gas industry. The objective of the current paper is to provide a novel method for bending moment estimates at the wellhead based on indirect moment measurements; this moment, together with fatigue properties are then used for fatigue damage estimation. Indirect bending moments are based on inclinations and accelerations measured by motion reference units (MRU) attached to blowout preventer (BOP), lower marine riser package (LMRP) and lower riser joint (LRJ) immediately above the lower flexible joint (LFJ). Also, required is the tension time history in the same period at the LRJ. The proposed methodology here can be implemented and integrated into a portal for data acquisition and visualisation.In order to validate the proposed method for indirect bending moment estimation, strain gages have been attached to a BOP and marine riser during drilling operations offshore Norway. Strain gage readings are transformed to bending moment which is used as reference (the so-called direct moment). The proposed method is used to calculate the moment indirectly, the so-called indirect moment. The resulting indirect moments agree very well with the direct moments.Copyright © 2015 by ASME
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Measured Wellhead Loads During Drilling Operations: Paper 1 — Data Processing and Preliminary Results
Volume 5B: Pipeline and Riser Technology, 2015Co-Authors: Massimiliano Russo, Urszula Wolak, Erling Myhre, Guttorm GrytoyrAbstract:The growing size of BOPs, longer drilling campaigns on wells, and operations in harsher environments has resulted in increased challenges in properly documenting wellhead fatigue during planned or executed drilling operations. The industry has started directing its efforts toward the calibration of analytical tools which are typically adopted for predicting wellhead fatigue. The ultimate goal for achieving this ambitious scope is to identify a benchmark set of analytical results that will predict field measurements. Early on Statoil identified a major obstacle: the absence of a good and comprehensive dataset of field measurements to serve as point of reference. Statoil and Aker Solutions cooperated on a pilot project with the intent of collecting a dataset of full scale measurements during drilling operations to be used to validate and calibrate the theoretical wellhead fatigue calculation methodologies. The main objective of the instrumentation campaign was to measure sectional forces as close as possible to typical wellhead hotspots by the use of three sets of strain gauges installed on the outside surface of the conductor and on the outside of the surface casing. With the objective of collecting an exhaustive dataset of measurements, accelerometers and inclinometers were installed on the BOP, the riser adapter, the riser below the upper flex joint and on the rig. An additional set of six strain gauges was installed on the riser to record riser tension variations. Environmental conditions were logged on board the rig and by the hindcast data provider. Operational events were carefully logged. This paper presents the following:• Data processing used for quality assurance and calibration of the measured data and the associated data challenges• Highlights of the instrumentation system capabilities to capture salient events of a typical drilling campaign and of ad-hoc performed rig operations to calibrate and validate the measured data• Effect of a controlled rig cross motion test, performed to evaluate quasi static loads on the well and calibrate strain gauge sensor orientations• A riser pull test, performed to validate strain gauge functioning• Several landing and disconnecting of the LMRP• Manipulation of the preload between the high pressure housing and the low pressure housing to investigate the effect of the preloading on the load sharing between the casingsSince King and Soloman [2], the industry is still lacking quality field data to be used in order to validate the various analytical models used in the analyses of subsea conductor and Wellheads. The results will confirm the quality of the measured data and will represent a first data point of comprehensive measured field data. This data will be used for future required work in calibrating the different building blocks pertaining to the analytical tools dedicated to well head fatigue predictions [3].Copyright © 2015 by ASME
W.s. Cowan - One of the best experts on this subject based on the ideXlab platform.
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Independent load support in an 18 3/4-in-, 15,000-psi subsea wellhead
Spe Drilling & Completion, 1993Co-Authors: W.s. CowanAbstract:Previous-generation subsea wellhead equipment was conceived as an extension of well-known surface wellhead equipment. Contemporary performance criteria for subsea wellhead equipment require new technology from the designer/manufacturer. This paper describes the role of a single design concept, independent load support, in adressing these criteria and illustrates the resulting configuration of a severe-service subsea wellhead system
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Independent Load Support in an 18 3/4-in., 15,000-psi Subsea Wellhead
SPE Drilling & Completion, 1993Co-Authors: W.s. CowanAbstract:Summary Previous-generation subsea wellhead equipment was conceived as an extension of well-known surface wellhead equipment. Contemporary performance criteria for subsea wellhead equipment require new technology from the designer/manufacturer. This paper describes the role of a single design concept, independent load support, in addressing these criteria and illustrates the resulting configuration of a severe-service subsea wellhead system. Introduction Traditional subsea wellhead design, dating back to the early 1960's, uses a high-pressure wellhead body containing one or more casing hangers and their annular seal assemblies or packoffs. The wellhead body includes a single internal annular shoulder, available in the difference between the sealing diameter [blowout preventer (BOP) size] and the minimum ID (bit size). The casing preventer (BOP) size] and the minimum ID (bit size). The casing hangers in the wellhead body land on this shoulder and on one another in sequence. The total downward axial load from casing weight and from the wellbore pressure end load thus is carried on this single shoulder, The size of this shoulder, and hence its bearing-support area, is fixed by the BOP and bit sizes for the first internal casing string (Fig. 1). These sizes are independent of the aggregate load that the shoulder must support. The load capacity of this shoulder eventually is overwhelmed by higher pressure, deeper and heavier casing strings, and hardness restrictions for sour-gas service. Even mechanical augmentation of that shoulder area is of limited benefit. The most appropriate design approach to the load limitations of conventional wellhead design is the use of independent load support. Put simply, this involves the use of multiple load paths into the wellhead bore, instead of a single path through the lower annular load shoulder. The use of multiple load paths is not new. Designers of "unitized" surface Wellheads previously provided individual annular load shoulders along the length of a multiple hanger head to support individual casing hangers. These shoulders were designed by taking the available annular area (from the BOP size and bit clearance) and dividing it into multiple. smaller shoulders. The drawback of this old surface wellhead design is that it offers no added load-bearing support area. Furthermore, the adjacent wellhead wall, upon which the packoff must act, has a different diameter at each hanger level. Consequently, the packoffs cannot be interchanged between the hangers. packoffs cannot be interchanged between the hangers. The limitations of traditional subsea wellhead design can be appreciated through consideration of the contemporary design criteria for subsea wellhead. In the discussion that follows, use of 18 3/4-in., 15,000-psi BOP's is assumed to be the most severe case for design of contemporary Wellheads.
Alain Bourgeois - One of the best experts on this subject based on the ideXlab platform.
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proceedings indonesian petroleum association thirtieth annual convention exhibition august 2005 nine inch x 10 000 psi wp dual conductor sharing Wellheads application on an offshore gas field development
2011Co-Authors: Jean-baptiste Pierre Faget, Jean-christophe Monneyron, Nicolas Payer, Alain Bourgeois, Liew Huey CherngAbstract:Splitter Wellheads allow several wells to be drilled from the same conductor pipe, which can bring significant benefits for conventional offshore developments by reducing the size and/or number of wellhead platforms or by giving access to additional reserves from existing platform slots.
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Nine Inch x 10,000 PSI WP Dual Conductor Sharing Wellheads Application on an Offshore Gas Field Development
2005Co-Authors: Jean-baptiste Pierre Faget, Jean-christophe Monneyron, Nicolas Payer, Alain Bourgeois, Liew Huey CherngAbstract:Splitter Wellheads allow several wells to be drilled from the same conductor pipe, which can bring significant benefits for conventional offshore developments by reducing the size and/or number of wellhead platforms or by giving access to additional reserves from existing platform slots. In April 2003, Cameron dual 9” CSW were successfully installed by Total E&P Indonesie on Peciko offshore gas field development as the first worldwide application of a 9” x 10,000 psi dual splitter wellhead and 4-1/2” x 6,500 psi Xmas-Tree. Thanks to this technology, 120 million USD could be saved on surface facilities by reducing the number of wellhead platforms from 10 to 7 while targeting the same gas reserves. Drilling and completion costs remained in line with initial plans, as the savings made with the slimmed down well architectures were counterbalanced by the higher well departures induced by the reduced number of platforms. To the end of 2004, 16 splitter wells (8 sets of dual CSW) have been drilled and completed without any major technical problem, 14 of them ahead of planning and below budget.
