Matching of Synchronous Motors and Centrifugal Compressors: Oil and Gas Industry Practice

2021 ◽  
Author(s):  
Matt Taher ◽  
Dragan Ristanovic ◽  
Cyrus Meher-Homji ◽  
Pradeep Pillai
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
Synchronous Motors ◽  
Industry Practice

Matching of Synchronous Motors and Centrifugal Compressors: Oil and Gas Industry Practice

2020 ◽  
Author(s):  
Matt Taher ◽  
Dragan Ristanovic ◽  
Cyrus Meher-Homji ◽  
Pradeep Pillai
Keyword(s):  
Centrifugal Compressor ◽  
Oil And Gas ◽  
Reactive Power ◽  
Oil And Gas Industry ◽  
Synchronous Motor ◽  
Variable Frequency ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
Variable Frequency Drive ◽  
Synchronous Motors

Abstract Synchronous motor driven centrifugal compressors are widely used in the oil and gas industry. In evaluating the optimum selection of synchronous motor drivers for centrifugal compressors, it is important to understand the factors influencing a proper match for a centrifugal compressor and its synchronous motor driver. The buyer should specify process requirements and define possible operating scenarios for the entire life of the motor driven centrifugal compressor train. The compressor designer will use the buyer-specified process conditions to model the aerothermodynamic behavior of the compressor and characterize its performance. Performance, controllability, starting capabilities as well as the optimum power margin required for a future-oriented design must also be considered. This paper reviews the criteria for evaluating the optimal combination of a centrifugal compressor and its synchronous motor driver as an integral package. It also addresses API standard requirements on synchronous motor driven centrifugal compressors. Design considerations for optimal selection and proper sizing of compressor drivers include large starting torque requirements to enable compressor start from settle-out conditions and to prevent flaring are addressed. Start-up capabilities of the motor driver can significantly impact the reliability and operability of the compressor train. API 617 on centrifugal compressors refers to API 546 for synchronous motor drivers. In this paper, requirements of API 617 and 546 are reviewed and several important design and sizing requirements are presented. In the effort to optimize plant design, and maintain the performance requirements, the paper discusses optimization options, such as direct on-line starting method to explore the motor rating limits, and the use of synchronous motors for power factor correction to eliminate or reduce the need for reactive power compensation by capacitor banks. This paper presents a novel approach to show constant reactive power lines on traditional V curves. It also complements capability curves of synchronous motors with lines of constant efficiency. The paper discusses variable frequency drive options currently used for synchronous motors in compressor applications. The paper addresses the available variable frequency drive types, their impact on the electrical grid, and motor design considerations with a view to summarizing factors important to the selection of variable frequency drives.

scholarly journals Optimization of compressor stations

2019 ◽  
Vol 3 ◽  
pp. 668-674
Author(s):  
Kurz Rainer
Keyword(s):  
Greenhouse Gases ◽  
Gas Turbine ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Operational Efficiency ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
Operational Characteristics ◽  
Efficiency Increase ◽  
Planning And Operation

Gas turbine driven centrifugal compressors are a mainstay in the oil and gas industry for upstream and midstream applications. For an increased effort to reduce greenhouse gases, one of the most promising efforts is the increase in operational efficiency. For the applications in the oil and gas industry, the efficiency increase come from increased equipment efficiency, or from increased operational efficiency. This paper is about increasing operational efficiency. The discussion will lead from the operational characteristics of gas turbine driven compressors to the characteristics of the application, and ways in planning and operation to optimize the system.

Rotordynamic Comparison of Built-Up Versus Solid Rotor Construction

2009 ◽  
Author(s):  
J. Jeffrey Moore ◽  
Andrew H. Lerche
Keyword(s):  
Stability Analysis ◽  
Critical Speed ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
7Th Edition ◽  
Multi Stage ◽  
Shrink Fit ◽  
Level 2

Most manufacturers of multi-stage centrifugal compressors for the oil and gas industry utilize a solid shaft rotor construction. The impellers use a shrink fit onto the shaft with spacers in between the impellers. With the introduction of the guidelines in the 7th edition of API 617, built-up rotors for centrifugal compressors using a tie-bolt are recognized by API. This study compares the rotordynamic performance of the identical compressor using both a tie-bolt design and a more conventional solid rotor for a two-stage pipeline application. A full API 617 lateral analysis is performed on the two designs, assuming identical impeller flow path, stage spacing, and hub diameter. The critical speed and unbalance response are computed, and a full Level 2 stability analysis is performed for each case. The results show the tie-bolt construction to be slightly lighter and stiffer, resulting in a higher critical speed and improved rotordynamic stability.

Optimization of perforation drilling for mitigating punch-through in multi-layered clays

2011 ◽  
Vol 48 (11) ◽  
pp. 1658-1673 ◽  
Author(s):  
M.S. Hossain ◽  
M.J. Cassidy ◽  
R. Baker ◽  
M.F. Randolph
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Soil Conditions ◽  
Gas Industry ◽  
Frequent Use ◽  
Layered Clays ◽  
Industry Practice ◽  
Offshore Oil And Gas ◽  
Drilling Rigs ◽  
Offshore Oil

“Spudcan” foundations for mobile drilling rigs continue to exhibit a high failure rate in the offshore oil and gas industry. The more frequent use of larger jack-ups in highly stratified regions, such as the Sunda Shelf in Southeast Asia, contributes to this concerning increase in “punch-through” incidents, which can lead to buckling of a leg or even toppling of the rig. An industry practice known as “perforation drilling” is sometimes used to mitigate the punch-through risk in layered clays, extracting soil from the upper strong layer before the jack-up is installed. This paper reports results from centrifuge model tests exploring the efficiency of perforation drilling. The soil conditions tested simulate offshore strength profiles that have reported punch-through failures. An experimental method for “drilling” sites in an enhanced gravity centrifuge environment was developed and the installation responses of model spudcan foundations penetrating through multi-layered clays with interbedded stiff layers were recorded. The experimental results show that the removal of soil inside the spudcan perimeter, with an area of 9% perforated, eliminated rapid leg run and severe punch-through on the two- and four-layer seabed profiles tested. This confirms the effectiveness of perforation drilling and indicates how the offshore drilling plan may be optimized.

Australia's shale industry – how we can become globally competitive

2019 ◽  
Vol 59 (2) ◽  
pp. 546
Author(s):  
Peter Cox
Keyword(s):  
Engineering Design ◽  
Life Cycle Cost ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Project Delivery ◽  
New Paradigm ◽  
Gas Industry ◽  
The Us ◽  
Pipeline Networks ◽  
Industry Practice

Project delivery technology is changing and developing at a rapid rate, and Australia’s oil and gas industry could do a better job of embracing change and getting to the forefront of advanced digital technology applied to developing onshore gas resources – particularly to our vast undeveloped shale reserves. Our shale deposits are in remote parts of our country, so present significant challenges, especially in relation to geographical distance away from local and international markets. This paper will focus on the use of automation and standardisation in the engineering design process combined with project execution strategies to significantly reduce both schedule and cost in delivering surface infrastructure required to get our gas shale reserves to both domestic demand centres and export facilities. The traditional project delivery models that have served us well in the past need to be challenged and a new paradigm adopted. Standardisation of the compression and dehydration facilities in the US market has been developed over many years, resulting in efficient project delivery, and enabling reserves to be brought to market on a fast track basis. This paper will work through practices in the US and how they can be applied to Australia. Australian standards and industry practice defines how we design our gathering and pipeline networks. This paper will present a combination of construction strategies and automation of engineering design to optimise life cycle cost in remote regions where construction mobilisation and logistics is a significant factor combined with changing priorities as further reservoir data is obtained from exploration wells.

Matching of Gas Turbines and Centrifugal Compressors: Oil and Gas Industry Practice

2012 ◽  
Author(s):  
Matt Taher ◽  
Cyrus Meher-Homji
Keyword(s):  
Gas Turbine ◽  
Centrifugal Compressor ◽  
Gas Turbines ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Site Conditions ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
Compressor Design ◽  
Selection Of

Gas turbine driven centrifugal compressors are widely used in the oil and gas industry. In evaluating the optimum selection of gas turbine drivers for centrifugal compressors, one of the main objectives should be to verify proper integration and matching of the centrifugal compressor to its gas turbine driver. Gas turbines are of standard designs, while centrifugal compressors are specifically designed to meet customer requirements. The purchaser should clearly specify process requirements and define possible operating scenarios for the entire life of the gas turbine driven centrifugal compressor train. Process requirements defined by the purchaser, will be used by the compressor designer to shape the aero-thermodynamic behavior of the compressor and characterize compressor performance. When designing a centrifugal compressor to be driven by a specific gas turbine, other design requirements are automatically introduced to centrifugal compressor design. Off-design performance, optimum power turbine speeds at site conditions as well as optimum power margin required for a future-oriented design must all be considered. Design and off-design performance of the selected gas turbine at site conditions influences the final selection of a properly matched centrifugal compressor design. In order to evaluate different designs and select the most technically viable solution, the purchaser should have a clear understanding of the factors influencing a proper match for a centrifugal compressor and its gas turbine driver. This paper discusses criteria for evaluating the most efficient combination of a centrifugal compressor and its gas turbine driver as an integral package from a purchaser’s viewpoint. It also addresses API standard requirements on gas turbine driven centrifugal compressors.

Performance Degradation Monitoring of Centrifugal Compressors Using Deviation Analysis

2012 ◽  
Author(s):  
Mohd Shahrizal Jasmani ◽  
Thomas Van Hardeveld ◽  
Mohd Faizal Bin Mohamed
Keyword(s):  
Centrifugal Compressor ◽  
Oil And Gas ◽  
Real Life ◽  
Oil And Gas Industry ◽  
Performance Degradation ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
Analysis And Evaluation ◽  
Deviation Analysis ◽  
Degradation Monitoring

Performance degradation monitoring of centrifugal compressor provides a means for the operators predict the behavior of their machines. Understanding the key principles in performance evaluation is essential for operators to benefit from this approach. In this paper, common performance degradation mechanisms found in centrifugal compressors for the oil and gas industry are outlined and related to their associated performance characteristics. Various analysis and evaluation techniques and approaches are elaborated with relevant requirements and assumptions for practical site application. A case study is also presented to demonstrate the application of performance degradation monitoring in a real-life operating environment. The benefits and limitations of the approach are also discussed. When combined with other condition monitoring approaches, this method provides a powerful tool to analyze and monitor centrifugal compressor performance which will then lead to useful recommendations for maintenance and operational interventions.

Explosion risk on offshore and onshore facilities—is there an explosion risk problem or an explosion modelling problem?

2015 ◽  
Vol 55 (1) ◽  
pp. 337
Author(s):  
Ingar Fossan ◽  
Sverre Nodland
Keyword(s):  
Gas Turbines ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Control Measures ◽  
Risk Level ◽  
Gas Industry ◽  
Industry Practice ◽  
Ultimate Outcome ◽  
The Difference ◽  
Explosion Risk

Management of the risk related to the loss of containment of flammable fluid is paramount to ensure safe operations at facilities processing or storing flammable fluids. According to best industry practice, an extensive set of safety functions—including measures that reduce the frequency of initiating events (e.g. leaks) and measures that mitigate consequences in case of ignition—are implemented in design to control the risk. Adopting the risk-based design principles that are commonly enforced in the oil and gas industry, the performance of implemented safety barriers are assessed both qualitatively and quantitatively using different methodologies such as hazard and operability analysis (HAZOP), failure mode and effects analysis (FMEA), and quantitative risk analysis (QRA). The ultimate outcome from the QRA methodology is used to assess the overall risk level as well as to assess dimensioning accidental loads (DALs) for equipment and structures that will ensure a design that is within the tolerable risk level set for the facility. An accurate assessment of DALs resulting from fires and explosion is crucial to manage both the risk and corresponding cost driving factors. The most critical safety barrier in this regard is to minimise leaks and thereafter to prevent ignition of the dispersed flammable fluid. A fundamental safety design principle is to find ways to avoid the occurrence of incidents rather than implement measures that mitigate consequences. This peer-reviewed paper demonstrates the significance of modelling the safety functions that are in place to ensure that the initial leak does not ignite by presenting a case example for different layouts of a conventional jacket installation with gas turbines. It is concluded that the difference between various available ignition models can be more prominent than the uncertainty related to any other model element in the QRA. To uncover potential hazards not reflected by the model and identify optimal control measures, the effect of the ignition model applied should be investigated in detail for installations where the QRA displays a prominent fire and explosion frequency.

Multivariate Regression Analysis for Screening Process of Reliability Assessment

2014 ◽  
Vol 567 ◽  
pp. 271-276
Author(s):  
V. John Kurian ◽  
M.C. Voon ◽  
Mohamed Mubarak Abdul Wahab ◽  
N.A. Iskandar ◽  
Mohd Shahir Liew
Keyword(s):  
Regression Analysis ◽  
System Reliability ◽  
Oil And Gas ◽  
Reliability Assessment ◽  
Oil And Gas Industry ◽  
Multivariate Regression Analysis ◽  
Regression Equations ◽  
Screening Process ◽  
Gas Industry ◽  
Industry Practice

Reliability is one major concern in the Oil and Gas industry to date. Reliability issues due to aging and increasing environmental loading are common for jacket platforms in Malaysia. Authors have studied system reliability assessment on existing jacket platforms in Malaysian waters and concluded that the current reliability assessment in the industry practice is tedious. The scope of the study includes regression analysis using three different methods to generate regression equation which could serve as a simplified reliability prediction model. Regression equations generated in this study seek to improve the current reliability assessment of jacket platforms in Malaysia by providing means for screening process before proceeding to tedious reliability analysis.

Mitigating Wellhead Fatigue While Reducing HSE Risk, Deck Spread, Deployment Time, and Crew Size

2021 ◽  
Author(s):  
Gunnar Ulland ◽  
Gunnar Hilsen ◽  
Stefano Croatto
Keyword(s):  
Fatigue Life ◽  
Oil And Gas ◽  
New Technology ◽  
High Capacity ◽  
Critical Factor ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Industry Practice ◽  
Drilling Operations ◽  
Deployment Time

Abstract Subsea wellhead systems have a design fatigue life that is expected to withstand the damage incurred from stress caused by cyclic loading during its operation. Wellhead fatigue is a critical factor when drilling offshore wells because the condition of the wellhead determines the length of time drilling activities can be carried out safely. The presence of the BOP on top of the wellhead affects fatigue life. Initially, these units were designed for 6-in. and 10-in. diameter casing and weighed slightly less than 1,400 lb. [ASME, 2003) Over time, BOPs evolved, and today's units are considerably larger and heavier than their predecessors, weighing in at approximately 400 metric tons. This increase in size and weight on the wellhead negatively impacts fatigue life. In recent years, the oil and gas industry has begun to look for ways to reduce wellhead fatigue to extend the life of the wellhead and expand the margins for safe drilling operations. A new ROV-operated Wellhead Load Relief (WLR) system, developed specifically to mitigate fatigue, uses special tensioners that are tethered individually to the BOP. Each tensioner contains a hydraulic spooling unit with a lock- and-pull mechanism that allows the ROV to tighten adjustable tethers subsea, pulling them from slack to a maximum tension of 35 metric tons. This approach to installation is a departure from common industry practice, which necessitates the configuration of the predetermined tether lengths on the topside. The ROV-operated WLR system described in this paper is a compact, high-capacity BOP tethering system suitable for both template and seabed anchoring. It provides a new and efficient way of tethering the BOP to avoid wellhead fatigue and delivers additional benefits that include minimized HSE risk, a smaller deck spread, decreased deployment time, and a smaller crew. The WLR system was operated subsea for the first time in December 2019. By precisely tensioning each tether and limiting the load transferred to the wellhead, the WLR significantly lessened wellhead fatigue, resulting in an almost complete halt in BOP movement. This new technology enables the operator to make optimal use of the fatigue life of the wellhead without compromising efficiency or safety.

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