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Pipelines
VOL. 15 ISSUE 3 MUMBAI US $ 10 ` 150
International Exhibition & Conference February 2020, Mumbai, India
CONTENTS
FEATURES Safe Design of Cross Country Pipelines VOL. 15 | NO. 3 | APRIL-MAY 2018 | MUMBAI | US $10 | ` 150 OFFSHORE WORLD R.NO. MAH ENG/ 2003/13269 Chairman Publisher & Printer Chief Executive Officer
EDITORIAL
Editor Feature Writer Editorial Advisory Board Design Team Subscription Team Production Team
Maulik Jasubhai Shah Hemant K. Shetty Hemant K. Shetty Mittravinda Ranjan (mittra_ranjan@jasubhai.com) Mahesh Kallayil (mahesh_kallayil@jasubhai.com) D P Mishra, H K Krishnamurthy, N G Ashar, Prof M C Dwivedi Arun Parab, Shankar Joshi Dilip Parab V Raj Misquitta (Head), Arun Madye
PLACE OF PUBLICATION: Jasubhai Media Private Limited
-V Sivakumar, Chief Engineer, Piping Design Department, TechnipFMC -R Balaji, Senior Principal Engineer, Piping Design Department, TechnipFM Thermal Expansion in Onshore Pipelines -Abhimat Singh, PMP, Senior Manager, Pipelines L&T-GULF Pvt Ltd. Commercialization of Adsorbed Natural Gas Technology
SALES
-Collin Gaskill, Product Development Engineer, Trelleborg Offshore Amit Bhalerao (amit_bhalerao@jasubhai.com) Prashant Koshti (prashant_koshti@jasubhai.com)
21
-Akash Gupta, MBA Senior Year, Rajiv Gandhi Institute of Petroleum Technology, Raebareli, Uttar Pradesh Polymer-based Solutions for Progressive Riser Technology
General Manager, Sales
16
-Juhi Garg , Project Engineer , Fluor Daniel India Pvt Ltd
210, Taj Building, 3 Floor, Dr. D. N. Road, Fort, Mumbai 400 001. Tel: + 91 -22-4037 3636, Fax: +91-22-4037 3635 rd
6
-J Moris Christopher, JGM, Piping Design Department, TechnipFMC
23
-Patrick Waal, Head of Sales, Trelleborg Offshore
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28
-Tarun Kant, Global Technology Solutions Leader for Engineering Software QuEST Global Services
Integrity Validation Revealed Severe Internal Corrosion on a Crude Oil Jetty Non-Piggable Pipeline
30
-A. K. Tewari, Executive Director (Operations), Indian Oil Corporation Limited -Deepak Agarwal, Inspection Manager, Pipelines Head Office -Ashish Khera, Director, Allied Engineers
MARKETING INITIATIVES VËœCONE FLOW METER SOLVES TEST SEPARATOR PROBLEMS FOR THE OIL & GAS INDUSTRY
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PRODUCTS
40
EVENTS DIARY
49
BOOK SHELF
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Kolkata Pune
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FEATURES
Safe Design of Cross Countr y Pipelines A long run pipeline carrying liquid or gas over long distance normally takes a route through different terrains such as rocky area, river crossing, highways road crossings, canal crossing, etc. In such routing pipeline integrity is very crucial as its failure can lead to huge safety and environmental issue to nearby society. This article will cover how the safe design of the gas pipeline to ensure this integrity was performed by TechnipFMC in a typical installation from gas gathering station to gas processing unit, considering the conditions such as - Design of pipeline for various terrain conditions including pipe thickness and burial depth; Stress analysis of the pipeline; Design of pipeline to take care of upheaval buckling; Measures for buoyancy protection; Special material requirements for pipeline and components; Surge protection; Cathodic protection; and Pipeline health monitoring.
T
ranspor tation of hydrocarbons is vital in a vibrant economy to meet various energy requirements. This shall be done in a safe manner with minimum impact to the environment and with least energy. Pipelines over long distances normally take a route through different terra in s su ch as ro c ky area, river cro ssing, sl op e d hil l s, highways, rail crossings, canal crossings, marshy land, etc. In such routings, pipeline integrity is ver y crucial as its failure can lead to huge safety and environmental issues.The safe design of pipeline star ts from the process design wherein line sizing is done for optimal energy consumption and to negate any impact of erosion induced pipeline failures. Due consideration shall be given for a High Integrity Pressure Protection System to protect the pipeline wherever required. In case of two phase flow, requirement of slug catcher may be explored. This ar ticle excludes erection, inspection, testing, operation, maintenance and pipeline routing in sensitive areas prone to wars and conflicts. Some of the key parameters for safe design of pipeline as experienced by TechnipFMC are indicated below. • Minimum cover for buried pipelines • Alignment Sheets • Materials • Thickness • Stress analysis • Surge Analysis • Cathodic Protection System • Pipeline Health Monitoring
Minimum cover for buried pipelines Pipeline passing through agricultural, hor ticultural occupancy, rocky terrains, industrial, commercial and residential area are buried with minimum depth of cover. Pipelines under drainages, ditches and road crossings are provided with extra depth of cover. www.oswindia.com
Canal / nala crossings, railway crossings and areas under tide influence are provided with additional depth of cover. Also, major river crossings are provided with more depth of cover with consideration of scour depth. Normally a higher thickness pipe is used at these locations. Alignment Sheets Alignment sheets graphically show the entire route of the pipeline, location, associated facilities and identifies the land masses associated with its placement and cover the following as minimum, • Centerline, outside diameter, grade and coating requirement. • Ground profile with intersections points along the alignment reflecting the elevations from Contour maps. • Details such as type of soil, hilly, wetlands, etc. • Details of crossings such as foreign pipelines, underground cables, river, canal, road and rail crossings • Other facilities namely block valve stations, surge facilities, choke valves, etc. Material M ate r i a l d e s i g n f o r p i p e l i n e d e a l s w i t h s e l e c t i o n o f a p p ro p r i ate material for the intended application and with due consideration such as sour and other corrosive ser vices. Material normally used are Carbon steel (with/without alloy cladding), Stainless steel, Nonmetallic plastics, etc., There are few special items exclusively used in pipelines. They are briefly described: • Barred Tee is a tee which prevents the pig from traveling down a branch connection • Choke Valve is for severe service oil and gas applications used for flow rates or pressure control. • Isolation Joint is to prevent detrimental electro-chemical interaction and improve the effectiveness of the cathodic protection
Offshore World | 6 | April-May 2018
Offshore World is an all-encompassing magazine for the hydrocarbon and allied industries. A bi-monthly magazine, launched in December 2003, Offshore World disseminates authen c, cri cal and well-researched informa on on global hydrocarbon industry innova ons. The magazine offers latest and strategic informa on on the upstream and downstream hydrocarbon industry. The endeavour of Offshore World is to become a vehicle in making “Hydrocarbon Vision 2025” a reality in terms of technologies, markets and new direc ons, and to stand as a medium of reflec on of the achievements and aspira ons of Indian hydrocarbon industry. Circula on: 25,370
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5% Hydrocarbon Explora on 10% Hydrocarbon Processing 20% Drilling and Equipment Manufacturers 10% Development and Produc on Companies 13% Transporta on and Logis cs Companies 12% Refining and Marke ng Companies 15% Plant, Machinery and Equipment Providers 10% Technology Solu on and Service Providers 5% Safety , Health and Environment
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• CEOs & Senior Management of Oil Companies • Petroleum Engineers & Refineries Contractors • Project Managers • Refining & Pipeline Engineers • Corrosion Control Engineers • Opera ons Managers • Technical Managers • Safety Managers & Engineers • Purchase Managers • Marke ng Execu ves • Pollu on Control Specialists • R&D Personnel • Industry Consultants • Engineering & EPC Consultants • Indian & Overseas Industry • Associa ons • Training Ins tutes
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FEATURES
Figure 1: Alignment Sheet (Courtesy: Indian Project, HOEC) •
Sand Trap is a component on downstream of pipelines to remove sand, debris and foreign particles that comes from well heads.
Thickness Thickness of pipeline is calculated based on ASME B31.4 for liquid lines and ASME B31.8 for Gas lines. Unlike process plant piping, emphasis to be laid on population density and environmental factors for thickness calculation by choosing the appropriate location class specified in the Code [1][2] . Stress analysis Stress analysis involves different conditions and Code [1][2] requirements compared to process plant above ground piping. Allowable stresses as per code are high compared to that of plant piping. Code classifies the line into Restrained (due to soil pressure) and Unrestrained lines. Pipe movements due to pressure elongation and thermal expansion must overcome the soil friction in underground conditions. The portion of buried piping which overcomes soil friction will move and create bending stress and the portion which doesn’t move, remains as it is. These transition points are called virtual anchors. Soil forces acting on the buried lines can be categorized into axial friction force and lateral soil force. Above Ground anchors and guides are used to absorb forces cascaded from buried line and to isolate the above ground piping from buried lines. Due to the non-linear nature of the buried pipelines, stress analysis gets complicated. Normally pipeline will expand towards the end or bend, due to restrained central por tion. End movement is directly propor tional to square of www.oswindia.com
the temperature difference bet ween line design and ambient/soil temperatures. To reduce the enormous bending at the ends, block anchors can be installed across the line at equal intervals. In addition, by making the soil tight around the lateral leg this stress can be reduced. If needed wall thickness of pipes and components can be locally increased. In pipelines buried under highways or railroad crossings, additional bending stress is created due to uneven soil pressure. Code requires that this bending stress to be combined with pressure hoop stress and the combined stress should be limited to specified minimum yield strength of the material. In addition to this normal Stress analysis, upheaval buckling, buoyancy effect in underwater are some of special stress checks done according to the terrain conditions to ensure safety of the pipeline. Upheaval buckling In buried pipeline, the soil resistance offered in lateral direc tions is different bet ween the direction above the pipeline and all other directions. This is due to continuous soil mass in other directions. This difference causes pipeline to buckle in the upward direction causing a lateral movement which will displace the pipeline from its intended buried elevation (Ref. Figure.2). When this upheaval is combined with seismic, the result will be catastrophic. Pipelines buried in ocean floors, marshy lands and river crossings will experience less soil resistance in the horizontal lateral directions due to the clumsiness of the soil. Palmers method [3] is used to evaluate this Upheaval buckling.
Offshore World | 8 | April-May 2018
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N.A
12 cms x 8.5 cms
FEATURES P – Effective axial force in operation (Due to Pressure & Thermal expansion) The pipeline lay imperfection (δ) caters to the upward load promoted by the effective axial force in operation (P). The pipe weights and the soil back cover density helps to reduce this upward load. Buoyancy force In case of pipelines on seabed or river bed, buoyanc y reduces the submerged weight of the pipeline thereby promoting buckling effect (Refer Figure-3). For a given diameter of pipeline this force is a constant. The pipeline weight can be increased by providing a concrete coating with necessary thickness. Although the increase in diameter due to coating increases the buoyancy, the density of concrete is high enough to make the increase in buoyancy negligible. Case Study A typical project executed by TechnipFMC had pipeline of size 12�, 12km long from Gas gathering station to Gas Processing Plant comprising above ground and buried portion. The pipeline was designed based on ASME B31.8. Analysis was done for operating loads, seismic effects and slug forces. Additionally, a river crossing of 500m width in the buried portion was analyzed for upheaval buckling and buoyancy effect using Palmers method.
Figure 2: Onshore Pipeline Uplift [4] Upward Load created In principle,
+ {đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ??…đ??…đ??…đ??…đ??…đ??…đ??…đ??…đ??…đ??…} by Upward AxialLoad created force} {compressive + {đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ?? đ??…đ??…đ??…đ??…đ??…đ??…đ??…đ??…đ??…đ??…} by Axial {compressive force} Should be less than
đ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒ đ??‹đ??‹đ??‹đ??‹đ??‹đ??‹đ??‹đ??‹ đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚ đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??” Should be less than đ??›đ??›đ??›đ??› + {đ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ť } to đ???đ???đ???đ???đ???đ???đ???đ??? đ??šđ??šđ??šđ??šđ??šđ??š đ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒđ??ƒ đ??‹đ??‹đ??‹đ??‹đ??‹đ??‹đ??‹đ??‹ đ??›đ??›đ??›đ??› đ??Źđ??Źđ??Źđ??Źđ??Źđ??Źđ??Źđ??Ź đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚đ??‚ đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??”đ??” đ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œ { } đ??›đ??›đ??›đ??› + {đ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ťđ??Ť } to avoid buckling. đ???đ???đ???đ???đ???đ???đ???đ??? đ??šđ??šđ??šđ??šđ??šđ??š đ??›đ??›đ??›đ??› đ??Źđ??Źđ??Źđ??Źđ??Źđ??Źđ??Źđ??Ź đ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œđ??œ { }
According to Palmer’s study the upward load (W) created in the operating avoid buckling. condition is given by, W = [1.16-4.76(EIw 0 _0/P)] * P *(δw 0 _0/EI) 1/2 w 0 - Installed Submerged weight (Pipe weight + Content weight – buoyancy force) EI – Flexural Rigidity δ- Imperfection Height (taken from piping layout)
The result 1 shows the uplift resistance is less than the required down load and the line will be unstable causing upheaval. To solve this a concrete coating with 80mm thickness was considered. The new results are given as result 2. The concrete thickness increases the weight and thereby increasing the uplift resistance (load) required to keep the pipeline without excessive buckling ensuring safe design. Surge Analysis Surge pressure occur when fluid flow velocity changes abruptly because of various scenarios like sudden closure of Emergency Shutdown Device,
Figure 3: Subsea Lateral Buckling [5] www.oswindia.com
Offshore World | 10 | April-May 2018
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About Magazine Offshore World is an all encompassing magazine for the hydrocarbon & allied industries. Offshore World disseminates authentic critical and well-researched information on global hydrocarbon industry innovations. For the industry professionals with the quest for enhancing knowledge, the magazine offers latest and strategic information on the upstream and downstream hydrocarbon industry. Offshore World endeavors to become a vehicle in making “Hydrocarbon Vision 2025” a reality in terms of technologies, markets and new directions and be a medium for reflecting the achievements and aspirations of Indian hydrocarbon industry. This highly reputed JS Group bi-monthly publication provides novel insights on the dynamics of Indian and global hydrocarbon industry.
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FEATURES Input Data Pipe external diameter
Result 2 0.324
m
Weight of empty pipe
3.273
kN/m
Pipe thickness
0.01031
m
Weight of pipe and content
3.844
kN/m
Pipe density
77
kN/m3
Buoyancy load
2.527
kN/m
203402000
kN/m2
Submerged weight
1.317
kN/m
Pipe elastic modulus (Young’s) Linear expansion coefficient
1.12E-05
°C-1
Pipe inertia
1.25E-04
m4
Poisson’s ratio
0.3
adm
Axial force
1481.64
kN
External anticorrosion thickness
0
m
Hoop stress
149.27
MPa
External anticorrosion density
0
kN/m3
Longitudinal stress
-78.24
MPa
Concrete coating thickness
0
m
Equivalent stress
200.20
MPa
Concrete density
24.525
kN/m3
Required down load
2.473
kN/m
Content density
7.91
kN/m3
Uplift resistance (load)
3.844
kN/m
13.734
kN/m3
Submarine water density Soil cover type (sand = 1, clay = 0) Soil effective density
0 17.658
kN/m3
Backfill cover
9.3
m
Shear strength (for clay)
0
kN/m2
Uplift coefficient (for sand) (dense sand = 0.5, loose sand = 0.1)
0
Pressure difference in the pipe
adm
9500000
N/m2
Temperature difference
54
°C
Bed imperfection amplitude
0.5
m
Result 1 Weight of empty pipe
3.273
kN/m
Weight of pipe and content
3.844
kN/m
Buoyancy load
2.527
kN/m
Submerged weight
1.317
kN/m
Pipe inertia
1.25E-04
m4
Axial force
1481.64
kN
Hoop stress
149.27
MPa
Longitudinal stress
-78.24
MPa
Equivalent stress
200.20
MPa
Required down load
2.532
kN/m
Uplift resistance (load)
1.354
kN/m
www.oswindia.com
pump tripping, slamming shut of a non-return valve etc. causing a pressure wave that moves from one end to another end at the sound speed inside the fluid. The wave therefore potentially subjec ts the pipe to exceed the pressure limits and leads to pipeline damage, pump casing crack , pipeline leak and by thus contamination and environmental damages. Non-per formance of surge study and improper surge protec tion will result in significant downtime and reduced life expec tanc y of pipeline. Damage may also occur due to pressure going below the minimum allowable operating pressures leading to cavitation and pipeline collapse. Hence, Surge analysis is an impor tant par t of pipeline design. To prevent failure of pipeline due to surge pressure the following methodologies can be adopted: • Surge pressure relief valves and surge tanks • Increased pipeline diameter / wall thickness • Increase valve opening and closing time Surge analysis gives force output at various support location which helps to design suitable pipe supports. Cathodic Protection System In buried pipeline corrosion is one of the major concern due to the environmental and the nature of the soil. External coating is one of the corrosion control measure and is achieved with methods like 3-Layer polypropylene or 3-Layer polyethylene or Fusion bonded Epoxy coating. The corrosion protection by the coating must be supplemented with cathodic protection to achieve complete mitigation of corrosion. Cathodic Protection to pipelines is provided by deep well anode beds, by installing at approximately 100 meter of distance from the pipeline. These anode beds are fed by Transformer Rectifier Unit [6] .
Offshore World | 12 | April-May 2018
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FEATURES During construction of pipeline, temporary cathodic protection is provided using Magnesium anode. In case of Overhead lines crossing, suitable electromagnetic interference study needs to be done. During the crossing of existing / foreign pipelines, one structure may act as cathode and other one as anode leading to corrosion and hence for such cases, the resistance bonding shall be inserted to create alternate path for current flow. Pipeline Health Monitoring Pipelines are normally running long length, high value, high risk and often require continuous monitoring. It is of fundamental impor tance to detect, diagnose and monitor damage growth as early as possible to predict the remaining operational life of a system and to minimize the risk of unexpected failures.
With proper considerations in material selection, stress analysis, support design, surge protections and careful monitoring the safe design of pipelines can be ensured. References 1. ASME B31.4: Pipeline Transportation Systems for Liquid Hydrocarbons and other liquids. 2. ASME B31.8: Gas Transmission and Distribution Piping systems. 3. Design of Submarine Pipelines Against Upheaval Buckling by Andrew Palmer and associates (1990). 4. www.ple4win.nl 5. www.anakkelautan.wordpress.com 6. www.raychemprg.com 7. www.yokogawa.com
Few of the Pipeline Health Monitoring systems are described below. Non-Destructive Evaluation Method This is a Non-Destructive Evaluation method routinely utilized in the petrochemical sector worldwide. Guided wave inspection enables the fully-volumetric inspection of several meters of pipeline from a single sensor location, since the entire volume of a pipeline can be monitored.
Authors J Moris Christopher JGM, Piping Design Department, TechnipFMC
Fiber Optics Sensing Method The fiber optic sensing leakage detection involves the installation of a fiber optic cable to measure the temperature over the entire pipeline length based on the Brillouin scattering or Raman backscattering effect. Leakages can be detected and localized using distributed fiber optic temperature sensors. Fiber optic distributed sensing systems can be used for distributed measurements of both strain and temperature over extremely long distances using a limited number of very long sensors.
Email : morischristopher.jesumarian@technipfmc.com V Sivakumar Chief Engineer, Piping Design Department, TechnipFMC Email : sivakumar.velayudhan@technipfmc.com R Balaji
Summary Long distance buried pipelines pose additional design requirements for safe operation during the intended life. Major constraint is the terrain in which the pipeline is routed providing various kinds of challenges to be met.
Senior Principal Engineer, Piping Design Department, TechnipFMC Email: balaji.ramadurai@technipfmc.com
Advisors B Sai Ramesh Vice President – Engineering TechnipFMC Email: sairamesh.babu@technipfmc.com A Mohan Vice President – Process and Technology, TechnipFMC Email : mohan.arunachalam@technipfmc.com
Figure 4: Raman Back-Scattering Technique [7] www.oswindia.com
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FEATURES
Thermal Expansion in Onshore Pipelines The thermal expansion in onshore hydrocarbon pipelines plays an impor tant role in designing the pipeline system. These pipelines are usually operated at high temperatures and pressures (well above the conditions under which the pipe was laid), and the resulting axial expansion can cause significant axial loads in the pipe wall. Buckling may occur in pipelines horizontally in lateral buckling on the seabed/ buried in loose sand, or ver tically in upheaval buckling of buried pipelines. Buried or trenched pipelines are restrained from expanding horizontally or laterally, and hence thereby not free to expand. If the force created by the pipeline is higher than the ver tical force produced by the soil cover which prevents against the uplift movement created by the pipe, the pipe tends to move upwards causing a ver tical displacement of the pipe that may eventually lead to pipeline failure. The design for the pipeline system must therefore include the mitigation measures of excessive expansion which includes installation of several anchor points, induction bends and change of existing soil strata etc. This paper shall discuss the methodologies used to restrict the thermal expansion in various stages of design – the practical implications of applying them and any potential limitations.
B
e it flowlines carr ying oil or gas from wellheads to processing plants or transpor ting products from one location to the other - pipelines are increasingly being required to operate at higher temperatures and pressures.As the pipe temperature changes from the installation condition to the operating condition, it expands or contracts. In the general term, both expansion and contraction are called thermal expansion. When a pipe expands it has the potential of generating enormous force and stress in the system.The natural tendency of a pipeline is to relieve the resulting high axial stress in the pipe -wall by buckling.
For the subjec t of discussion, this paper shall focus on the ‘Onshore P i p e l i n e s’ w h e re b y c a u s e s, m i t i g a t i o n m e a s u re s a n d a s s o c i a t e d design considerations associated for Pipeline thermal expansion shall be reviewed.
I n O f f s h o re p i p e l i n e s, b u c kl i n g i s s e e n to b e ca u s e d by t h e a x i a l compression formed along the pipelines due to large temperature differences and high internal pressure. Buckling may occur in pipelines d ow nwa rd i n a f re e s p a n , h o ri zo nt a l ly i n l ate ra l b u c kl i n g o n t h e seabed, or ver tically in upheaval buckling of buried pipelines. However buried or trenched pipelines are not free to expand horizontally or laterally, and thus develop an axial compressive force due to the restraint. When the force exer ted by the pipeline exceeds the ver tical restraint that resists the uplift movement (created by the pipe’s size and submerged weight, the bending stiffness of the pipe, and the weight of the soil or rock cover), the pipe tends to move upward which results in a ver tical displacement that can cause struc tural deformation or failure of the pipeline.
2.
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UPHEAVAL/ LATERAL BUCKLING: By definition, a buried pipeline is fully restrained. However, portions there may be sections of the line that may become partially restrained when: 1.
There is a transition from below-grade to above-grade installation Directional changes occur (lateral bends, over bends, and sag bends) in soil where the ultimate soil strength is not adequate to fully resist pipe movement.
Internal pressure and thermal loading due to the difference between the pipe installation temperature and the operating temperature can create large compressive forces in the pipe. These large compressive forces tend to cause the pipe to move upward at over bends, downward at sag bends, and laterally at horizontal bends. There is a relatively high degree of resistance to downward and lateral movement that will restrain the pipe due to the bearing capacity of the surrounding undisturbed soils. There is less resistance to the upward movement, which may lead to upheaval of the pipe for high operating temperatures.
Offshore World | 16 | April-May 2018
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FEATURES cause upheaval buckling, the pipeline may be more liable to a different but related mode of buckling, in which the pipeline snakes laterally across the ground. This phenomenon is called lateral buckling. This buckling may occur depending upon the imper fec tions and/ or the lateral soil resistance. Late ra l b u c k l i n g i s l e s s l i ke ly t h a n u p h e ava l b u c k l i n g f o r b u r i e d pipelines. Buried pipeline trenches have stronger restraining forces available from the trench walls than from trench backfill. With these higher restraining forces, the line lateral buckling is less expected, however, at horizontal cold form bend locations along the route it is impor tant that minimum distance between any pipeline and the trench wall should be maintained. The figures show a sequence of events which initiate upheaval buckling in buried pipelines (Figure 1) and direction of axial forces acting on buried pipelines (Figure 2).
Figure 1:
Fo r l a rg e co m p re s s i ve l o a d s, t h e p i p e l i n e re s p o n s e m a y b e co m e unacceptable in terms of vertical displacements (the pipe protruding from the ground, i.e., through the cover over the pipe, or moving out of the trench), excessive yielding of the pipe material, or both. This phenomenon is normally isolated, is confined to the bent pipe segments, and is called upheaval buckling. For the structural integrity of the pipeline, it is desirable either to completely eliminate any possibility of upheaval buckling or to ensure that the buckling occurs within a tolerable range, i.e., within the elastic limit of the pipe material. In case of above ground pipeline that is neither trenched nor buried, and has no ver tically imperfect segments that are significant enough to
In figure 1 the pipeline is laid across an uneven ground profile (a) and later trenched and buried (b). The trenching and burial operations modify the profile of the grade on which the pipe is resting, so that it is not precisely the same as the original profile. Trenching may smooth the profile overbends, but may also introduce additional imperfections, if, for instance, a lump of bottom soil falls under the pipe (d). Mentioned below are few of the approaches widely accepted to reduce the propagation of upheaval buckling. 1.
Limiting the change in direction of Pipelines to a maximum permitted angle: As Pipelines buckle at the bend locations hence limiting the bend angle to maximum permitted level mitigates the upheaval buckling. The maximum permitted bend angle is computed from special calculations as per Dr.K.Peters method which is widely
Figure 2: www.oswindia.com
Offshore World | 18 | April-May 2018
FEATURES • Effective Axial Force in Constrained Pipe can be calculated as per Eq. no.1 of Technical Paper by K Peters) Hoop Stress (SH) = PDo/ 2Tw Compressive Longitudinal Stress (SL) = (Eα∆T) – (µSH) Compressive Restraint Force (F) = (E x α x ∆T x AS) + [(1-2µ) x P x Ai]…( where, E = Young’s Modulus
Figure 3:
being followed in the Middle Eastern countries as well as the other parts of the world. The calculations provide the maximum permitted change of angle of pipeline for a given design condition, soil bearing capacity and depth of cover. (The correlations are briefly explained in the further section). 2.
3.
4.
5.
In addition to K.Peters method, Technical Paper OTC-6335 and Shell DEP 31.40.10.16- Gen are also widely accepted methodology to carry out the required calculations. Providing extra Soil cover at certain critical locations: At locations where the bend angle is greater than the maximum permitted level the extra soil cover is provided so that force created by the pipelineis lower than the ver tical force produced by the soil cover which prevents against the uplift movement created by the pipe, the pipe then tends to move upward causing a ver tical displacement of the pipe. Replacing the existing soil strata with superior backfill material: At locations where the bend angle is greater than the maximum permitted level, the existing soil can be replaced with superior gatch material/ rocks materials having greater bearing capacity so that ver tical force created by soil cover is increased. Expansion loops for above ground pipelines: Generally oil and water flowlines from well head are installed above ground. The installation can be either sur face laid or laid on sleeper suppor ts. In either of installation the above ground flowline has tendency to move laterally due to temperature change. By providing expansion loops at regular inter val the expansion of pipelines are absorbed.
CALCULATING MAXIMUM PERMIT TED PIPE BEND ANGLE AND DEPTH OF COVER OF PIPELINE The following co-relations from Technical Paper by K Peters are universally used:
α
= Co-efficient of Thermal expansion
∆T
= Difference in Temperature (Operating – Installation)
P
= Design Pressure
Ai
= Pipe Internal Area
As
= Pipe Cross sectional Area
µ
= Poisson’s Ratio
• Effective length in which buckling occurs can be calculated as per Eq. no. 21 of Technical Paper by K Peters) Buckling Length (LB) = sqrt [(4π2EI)/ F] Where, LB = Buckling Length E
= Young Modulus
I
= Moment of Inertia
F
= Compressive Restraint Force
• Ultimate Soil Resistance to resist upward movement of pipe can be calculated as R = q+ Wo Where, Uplift Resistance Per Unit Length for Uncompacted Back Fill (q) = (γS H D0) x (1+f (H/D0)) γS = Unit weight of soil, f
= Uplift Resistance co-efficient
H
= Depth of cover
• Allowable Remaining Stresses can be calculated as Allowable Bending Stresses (SB) = (0.9 SMYS) – (SL + SH) • Finally the Allowable Bend Angle can be calculated as per Eq. no. 25 of Technical paper by K Peters) Condition to get final n Value by iteration= (1- (π x n cos(πn)/ sin(πn))/2 = SB x F / (DO x E x R) Allowable Bend angle in Radian = n x LB x RF
Offshore World | 19 | April-May 2018
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FEATURES • The Allowable Depth of cover can be calculated as per Eq. no.28 of Technical Paper by K Peters
in providing expansion at its ends. The vir tual anchor length is also computed via Caesar II and AUTO PIPE.
HR= (DO/f ) x (sqrt (([RR-WO)*f ]/(ÎłS*DO2))+0.25)-0.5)
CONCLUSION The effects of thermal expansion of pipeline are important to be analysed and can result in failure of the pipeline. The construction engineer must decide the grading profile of the pipeline after evaluating the maximum permitted bend angle and required depth of cover of pipeline. Further the requirement of Anchor block must be finalized during the stress analysis in order to prevent overstressing of the terminal piping and failure of pipeline at underground and above ground transition point of pipeline. All expected cases that can be encountered during entire design life of the pipeline must be analysed in stress analysis.
E F F E C TS O F T H E R M A L E X PA N S I O N AT P I P E L I N E TERMINALS: At the star ting and terminating ends of pipeline the one end of pipeline is unrestrained. The pipe temperature changes from the installation condition to the operating condition causes the expansion in above ground por tion of pipelines inside the terminals. The expansion of pipelines is a result of hundreds of tons of force pipelines are carr ying. These expansions if not limited results in failure of pipelines and plant piping inside the terminal by increasing the stresses beyond the permissible level of code requirements. Following are few mitigation methods of reducing the displacement at start and terminating ends of pipeline: 1.
1.
1.
REFERENCES 1.
Technical Paper by Dr K Peters (Upheaval and lateral buckling of embedded buried pipelines)
Installation of Anchor Block: An anchor flange is welded to the pipeline which is encapsulated completely by a block of concrete called Anchor block. The anchor block though expensive c a n re d u ce t h e d i s p l a ce m e nt o f p i p e l i n e s e nte r i n g i nto t h e terminal. The expansion of pipeline is measured from the Stress analysis of pipelines using universally accepted soft wares like Caesar II and AUTO PIPE. Change in routing of pipeline: Possibility of change of routing of pipeline entering inside the terminal is reviewed and endeavours are made to include horizontal bends so that the expansion areabsorbed by the bend. This is the most cost effective method to restrict the expansion of pipelines entering inside the terminal. Provision of expansion of pipeline inside the terminal: The designer models the pipeline system inside the terminal in such a way that there is adequate flexibility in the system to absorb cer tain amount of expansion of pipeline. The Pig Launcher and receiver supports are provided with sliding support having free slots (generally 100 mm) to allow pipeline to expand. The entire system including terminal piping and scraper trap system is reviewed in stress analysis so that system is well with the allowable code limit of ASME B 31.4/ B31.8.
For stress analysis the pipeline is modelled upto vir tual anchor length. The vir tual anchor length is defined as the length of pipeline from its star t which has its effect on the displacement at terminals. Hence the pipeline, which is beyond the vir tual anchor length do not assist www.oswindia.com
Offshore World | 20 | April-May 2018
Juhi Garg Projec t Engineer Fluor Daniel India Pvt Ltd Juhi.Garg@fluor.com
Abhimat Singh, PMP Senior Manager, Pipelines L&T-GULF Pvt Ltd. Abhimat.Singh@larsentoubro.com
FEATURES
Commercialization of Adsorbed Natural Gas Technology Fossil fuels, the foremost sources of energy for today’s society, whether it be a developed or a developing nation all have its dependence and thus the need arises to look for the environment in accordance with the market as well. Natural Gas is a fossil fuel used for several of its uses these days being a clean source for energy and its nature of producing less pollution in comparison to other sources prevalent. There is this latest technology called Adsorbed Natural Gas Technology which follows the concepts of adsorbing the natural gas in special micro-porous material on room temperature thus allowing to refuel the tank with simple and cheap equipment. The ANG technology enables to store similar gas quantities as compressed natural gas under much lower pressure and thus decreases the filling station capital and operation cost besides natural gas end-user cost. With this technology the there comes the need for the development of the infrastructure to implement it, the method to install it and the requirement of market to cater it.
T
he fast pace with which the world is moving towards the energy sources those are cleaner and have low-carbon content dictates the stor y of the transformation that has taken place from the consumption of Diesel & Petrol to Natural Gas to Green Fuels. And this itself explains that the shift of Conventional to Unconventional fuel is not much smooth as it brings the challenges that needs time to be resolved. With present rate of consumption, these conventional fuel (fossil fuels) are near to their depletion and thus the shift is ver y much needed and thereby the consumption of Natural Gas (NG) for major primar y purposes is on the rise. Natural Gas being more advantageous than other hydrocarbons fuels offering greater reduction in Carbon monoxide, Nitrogen oxide, and Non-methane hydrocarbon emissions and is promisingly used as fuel for vehicle application, being cheaper than petrol and diesel. Presently, natural gas is used by compressing it under high pressure (17.2- 20.7 MPa) in order be stored in a substantial amount, called as Compressed Natural Gas (CNG). However, these high-pressure leads to several problems related to the storage system; cylinder corrosion, possibility of explosive leak of the gas, etc., which becomes the main cause for NG not to be used for vehicular application. But there is this Adsorbed Natural Gas (ANG) Technology, which presents us with whole new perspective to store the natural gas in a lot more safe and convenient manner. Adsorbed Natural Gas technology stores natural gas over these materials that act a sponge to adsorb the natural gas. It allows substantially higher concentrations of gas to be stored, without requiring any refrigeration methods or equipment. It takes place at relatively low pressure around 3.5 MPa, achievable by single stage compression and can provide same capacity as compared to CNG. Specifically, for the vehicular application of this technique, maximum
gas storage density becomes the utmost requirement to achieve the desired level of mileage range. For bulk storage of gas through this method the viability depends upon: • Selection Adsorbing material •
Storage per volume stored (v/v)
•
Density of the Adsorbent
•
Cost of Material
•
Amount of material to be used
•
Size of the container (in which the adsorbing substance will be kept)
Activated Carbon, made from the Coconut shells or Peach stones, are subjected to either chemical impregnation followed by heating or are first pyrolyzed to carbon and then subjected to steam treatment. Some other adsorbent could include Graphene, Metal-oxide frameworks, etc. The microscopic physical proper ties and electro-chemical proper ties of the adsorbent enable 10 to 100 times the amount of gas to be stored in a given volume of pressure compared to the conventional compressed gas storage (on a given sur face area). Generally, a good adsorbent should has following proper ties: •
A porous structure with high surface are to volume and weight ratio.
•
Physically and Chemically stable
•
A relatively good conductor of heat for adsorption and desorption cycle
•
Economical to manufacture
•
Easily recycled
The process involved in the whole procedure is, adding up of the NG to a storage system, called adsorption (exothermic process), withdrawing
Offshore World | 21 | April-May 2018
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FEATURES
Source: https://ngtnews.com/ingevity-angp-announce -plans-adsorbed-natural-gas-tech of the gas from the storage system, called as desorption (endothermic process), which is as the pressure begins to drop in the system, the methane molecules are released from the sur face of the adsorbent material into the gaseous state. There are thermal changes involved while the adsorption and desorption processes are going which also affects the discharge rate of the gas. When it comes to the commercialization of any technology the parameters used to evaluate are to be taken care of and likewise, the evaluation of the per formance of various adsorbents is based upon the amount of gas retained in the adsorbent at the end of a desorption cycle. The absolute uptake is the total amount of gas adsorbed on the initial adsorption cycle, noted as “V/V”. the working capacity denotes the gas delivered on a desorption cycle. There are near to no technical obstacles prohibiting the construction of an ANG storage system, as all the components are already in use for CNG applications, with some technical changes required for the newer technology. There will be a paradigm shift in terms of the benefits that could be incurred on implementing ANG technology (low pressure on-board natural gas), like: •
Enables fueling of the NG on private/individual basis due to low compression requirements
•
Comfortable low weight storage tank
•
Lowers the cost of every fuel consumed (petrol/diesel)
•
75% reduction in carbon monoxide emissions*
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•
55% reduction in volatile organic compounds*
•
50% reduction in nitrogen oxide emissions*
•
Up to 30% reduction I carbon dioxide emissions*
(* Source: Southern California Gas Company and the 2008 TIAX, LLC Repor t Well-To-Wheels, prepared for the California Energy Commission) Recently, several organizations are joining hands to bring for ward this technology and to commercialize it in a more adaptable manner like, Ingenvity had par ticipated in a corporate coalition with Adsorbed Natural Gas Products, Inc., United Technology Research Center, and Wor thington Industries (U.S.A based firms) # Today the society is tr ying to help the environment in ever y way possible and ANG technology do possess some hidden benefits for the world to explore. Innovation, Development and Implementation are the 3 pillars that enable any technology to cater the society, so let us tr y to fill-in the gaps to reap fruits from this technology.
Offshore World | 22 | April-May 2018
Ak ash Gupta MBA Senior Year R ajiv Gandhi Institute Of Petroleum Technology, R aebareli, Uttar Pradesh E-mail: akashgpt499@gmail.com
FEATURES
Polymer-based Solutions for Progressive Riser Technology Using advanced polymer material technology, Trelleborg’s offshore operation provides high integrity solutions for the harshest and most demanding offshore environments. The company specializes in the development and production of polymer and syntactic foam based seismic, marine, buoyancy, cable protection and thermal insulation products, as well as rubber-based passive and active fire protection solutions for the offshore industry.
T
he oil and gas industry is renowned for continuously pushing the limits. The exploration of offshore oil and gas continues to move into deeper waters and the demands for drilling operations to perform faster and more effectively to provide higher cost savings and safe well completions, have grown. Adding to this challenge is the requirement to extract more oil and gas than ever before and exploit ever harsher reservoir environments in new locations around the world. With these challenges in mind, we look at why next-generation corrosion-free, polymer-based solutions can be the vital element to ensuring the protection of people, structures and equipment on offshore risers from surface to seafloor. Exceeding Expectations Although technology has advanced to better address the ever-changing needs of the offshore environment, customers still require superior, costeffective solutions with an increased focus on onboard safety and extended service life; increasing to up to 40 years from 20 years. For both of these focus areas, choosing the most appropriate material is imperative and not surprisingly, polymer materials are becoming a more popular choice within the offshore industry. Polymer-based materials such as rubber and polyurethane are naturally flexible and very durable. Compared to alternative materials, such as steel, ceramic wool or fiberglass, polymerbased materials can withstand greater temperature extremes, weather conditions, and vessel movements while offering an exceptionally high
durability. It is a diverse group of materials that can perform at every level to damp, seal and protect, and most of all has an extremely long lifespan. Safety for Challenging Environments It is no surprise that onboard safety is a key priority for the offshore riser platforms, but this is becoming progressively difficult in increasingly challenging environments as installations move further offshore. Advanced fire protection systems are critical to ensuring onboard safety, whether it is the platform’s surface protection, an onboard deluge system or coating for the pipes and flanges for example. The performance of these systems is essential for the safety of personnel, asset protection and preventing fire escalation. So, in the offshore oil and gas sector where the risk of uncontrolled, rapid fire spread is greater than most, firestop solutions need to provide full assurance to the onboard team that they will not fail to protect against fire. If damage is caused, costly shutdowns and repairs would be required and in the worst-case scenario, the platform may fail altogether. The harsh offshore weather environment causes metal products and components to be susceptible to rust and corrosion, which is detrimental to the performance and function of the platform. Additionally, ceramic wool and similar materials used for fire protection will become less effective when wet. These less than optimal solutions simply are not an option when protecting people, structures, and equipment. Passive Fire Protection Passive fire protection solutions are available in a series of materials and products to protect personnel, equipment, critical components and structures, and to assist emergency response activity by buying time to gain control of the fire and evacuate the area. With proven engineering and manufacturing techniques for protection of all kind of fires, from cellulose to hydrocarbon and jet fire, rubber materials, which are built-up with layers that meet corrosion, thermal, fire, and mechanical protection requirements, protect structures from exceeding temperature limits. Rubber has the unique
Offshore World | 23 | April-May 2018
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FEATURES
capability of withstanding weather conditions, vessel movements, providing ease of inspection and fire protection over the life of a project, which could extend over 40 years.
nature of rubber-based materials protects equipment from vibration, collisions, explosions and earthquakes. Topside applications
Throughout the fire exposure period, it is key that any fire protection specified for use on an offshore facilit y provides the required fire protection and integrity; protecting areas between modules and decks to prevent the spread of flames and hot fumes. The critical temperature on the surface of a component is project specific information, with typical values of +392 °F to +752 °F. Similarly, in accordance with the Health and Safety Executive (HSE), the generation of smoke and non-toxic fumes must remain low. Additionally, the dampening, noise reducing, flexible
Laydown Decks The platform laydown deck areas are susceptible to regular impact and abrasion due to containers being loaded onto the platform, as well as to the harsh offshore elements. Before fire protection is considered, the deck should be protected against chemical and mechanical conditions and ensure that it is resistant to fatigue. A flexible decking material capable of withstanding these conditions is an ideal solution. Rubber provides the corrosion protection in addition to environmental and impact protection, while maintaining the required fire protection rating. Surface tiling should feature insulation to isolate fire temperatures from areas below and should also ensure a non-slip surface for worker safety. The flexibility of a rubber-based tile means that it can take up movement in any direction, reducing the likelihood of cracking. Similarly, as tiles are regularly exposed to the sun, it ensures UV and ozone protection, so that surface is not damaged over time. Flanges Considered as one of the weakest areas of any platform or refinery, fire protection for nuts and bolts used in flanges should be considered. Typical fire protection covers the complete flange with a housing, not allowing for easy inspection of the units. By using a molded rubber-based material on just the flange nuts, the stud bolts are protected from elongating and
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Offshore World | 24 | April-May 2018
FEATURES
the flange from breaking the seal during a fire. Installation is simplified, lowering installation times, regular inspection is facilitated, and overall weight is lowered. Fire Deluge Systems With a large number of aging platforms and rigs currently in operation and the threat of critical failure looming, onboard deluge systems this one
application in particular where benefits from flexible fire protection will help reduce fire risks and potential downtime or closure. By choosing a flexible, rubber-based material, these deluge systems are non-corroding and can withstand jet fires with a heat flux of 390kW/m2, temperatures above +2552 °F. Extending service life though corrosion protection One of the most effective methods of extending the service life of a riser is to protect it from corrosion, particularly in the highly corrosive splash zone region. The splash zone is the area immediately above and below the water’s surface and is a major corrosion concern for offshore installations. As the water level rises and falls the metal surfaces of the riser are alternately becoming wet and dry, which causes the metal to corrode when the saline water is exposed to oxygen. External surfaces exposed in the splash zone should be protected with special corrosion protection systems. Rubber-based coating on risers as a form of corrosion protection is an extremely popular solution and is widely recognized in the offshore industry as the most effective method of riser corrosion protection particularly in the highly corrosive splash zone region. When selecting a corrosion coating for a riser, manufacturers should ensure that the supplier they select can fully customize the coating material to meet the specific project needs. Most rubber-based solutions can incorporate a range of protective qualities such as anti-fouling to inhibit marine growth. Additionally, rubber-based corrosion protection solutions are resistant to
Offshore World | 25 | April-May 2018
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abrasion, chemicals, wear, blast, impact, jet fire, ozone, UV and salt water. An important feature of any riser corrosion coating is the fact that the coating is chemically bonded to the metal surface or substrate permanently and will not crack or disbond. As a material specifically engineered to protect against sea and weather conditions, rubber corrosion coatings will guard against corrosion for the lifetime of the riser. In addition to the splash zone, rubber-based riser corrosion protection can be applied to as a robust rubber lining for any exposed steel components located on a riser. Riser protection surface to seafloor The drill riser provides a conduit for the drill string and drilling fluids from the ocean floor to the rig. A drilling riser typically has a large diameter, lowpressure main tube with external auxiliary lines that include high-pressure choke and kill lines for circulating fluid. All of these lines need to be protected during handling, storage, deployment, retrieval and drilling operations. Some of the most trusted protection systems for bare riser joints include polymer-based protection covers. These protection covers are manufactured
from polyurethane or polypropylene and are specifically designed to protect the drilling riser from impact damage when running or retrieving through the drill floor and moon pool area or during handling operations in the riser storage bay. Drilling risers, which can reach lengths of 10,000 feet or more and weigh millions of pounds must be kept in tension to ensure safe operation of the equipment. In order to reduce the requirement on vessel tensioning systems to a more manageable level, discrete buoyancy units can be fitted along the length of the riser to reduce the weight of riser joints in water. These buoyancy units are made out of a polymer-based foam that not only reduces the weight of the riser string to a manageable amount but also protects the riser and auxiliary lines from impact and abrasion subsea. Taking protection to the next level, a newly designed and tested helically grooved buoyancy option is available on the market that not only optimizes uplift, it also effectively eliminates riser motions and higher levels of drag in onerous offshore current environments compared to traditional riser buoyancy. The new multi-functional solution integrates the technology to suppress vortex-induced vibrations (VIV) and reduce drag into riser buoyancy equipment during manufacturing, essentially eliminating the requirement of ancillary suppression equipment, alleviating complicated and time intensive riser running and retrieval procedures. Similarly, buoyancy technology is used to offset tension loads on deep water umbilicals and risers for floating production systems. Distributed Buoyancy Modules are used to reduce the top tension loads by providing uplift to sections of the riser to generate pre-defined configurations that allow the vessel a full range of surface movement without putting undue stress on subsea lines. These configurations include “Lazy Wave”, “Steep Wave”, “Lazy-S”, “Steep-S”, and “Pliant Wave”. Evolving riser technology for the future As complicated exploration and production activities target more challenging reservoirs, an evolution of current riser technology will be required to ensure
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Offshore World | 26 | April-May 2018
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continued safe and cost-effective operations. Advanced engineering analysis and simulation design tools provide the ability to effectively develop new riser equipment technologies considering the real world environmental and operational challenges they will be required to perform under. Computational Fluid Dynamics (CFD) analysis studies provide the means for exploring optimized equipment designs with consideration of minimizing hydrodynamic loading. Riser technology can be successfully designed to be multifunctional, suppressing VIV and reducing drag simultaneously while performing its primary protection and buoyancy roles. Local and global Finite Element Analysis (FEA) allows for equipment to be designed smarter, minimizing required size and material while optimizing loading paths, performance, and design lives. Employing these advanced engineering tools will help advance riser technology moving into the future to expand and extend the capabilities of the industry.
will be increased. In the harsh offshore oil and gas industry, operators need the assurance of a material that delivers proven performance, without fail. It is the responsibility of the manufacturer to ensure that they can provide high performance and reliable solutions, now more than ever. Similarly, operators should look to work with manufacturers who can provide the most advanced solutions which will guarantee performance and importantly, safety.
Conclusion While deep-water drilling and production has been revolutionized by increasingly advanced technology in recent years, making high performance and dependable solutions has never been more important. This is because the requirement for equipment to operate safely and effectively while providing peace of mind is becoming more challenging in these demanding and dangerous environments. By installing effective and reliable polymer riser protection systems, the safety of hydrocarbons transportation installations Offshore World | 27 | April-May 2018
Collin Gask ill Produc t D evelopment Engineer Trelleborg Offshore Collin.Gaskill@Trelleborg.com Patrick Waal Head of Sales Trelleborg Offshore Patrick.Wall@Trelleborg.com www.oswindia.com
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Why is the Oil & Gas Industr y Mining Data? With data being the new oil, it’s apparent that Oil & Gas (O&G) companies can reap myriad benefits from mining data along-with oil & gas. Real-time access to information can empower them to derive actionable insights from the zettabytes of geo-spatial data such as seismic maps, well logs, equipment parameters, etc. Be it upstream, midstream or downstream – global O&G giants are building on their capabilities thru engineering Data Analytics leveraging both edge and cloud platforms. With benefits ranging from optimizing reservoir throughput to autonomous drilling, predictive maintenance of equipment, Monitoring refining and pipeline infrastructure they are arming themselves with leading-edge technologies such as Edge analytics, Deep Learning, Machine learning to make every drop of crude oil count.
T
here is an age-old business rhetoric which has stood the test of time. It goes something like ‘If you can’t measure it, you can’t improve it.’ Just like the sun rising in the east, this saying has proven to be a universal truth in every sphere of modern life. Be it the Wall Street stock markets or the oil-fields around the world; data has proved to be that omnipresent and omnipotent measurement tool upon which sustainable business continuity depends in the modern world. Moreover, low-cost energy being an imperative for every successfully thriving society, the Oil and Gas (O&G) sector has always been innovating to improve its technology with data while searching and tapping ear th’s dwindling hydrocarbon reserves. Illuminating Dark Data As both the natural crude oil reserves and the man-made demand for refined petrochemical products mandated a lot of information gathering and number crunching, since inception itself the O&G industr y has been drilling and dealing with data to arrive at concrete business insights. Weathering the storm of dynamic economic trends, geopolitical developments and technological innovations, the O&G industr y has evolved with multi-faceted and rigorous data practices. With the advent of the digital since the nineties, O&G companies had focused on data acquisition by using sensors rather than periodic human supervision in every phase of the petrochemical exploration, production and distribution process. The data thus captured such as 3D seismic images, machinery performance indicators, oil flow rates, crude pressure reports and many more data points required colossal storage. This was followed by the data integration phase that was characterized by the efforts to centralize the data captured from various sensors into a single console for the geoscientists and engineers to analyze manually. Since the dawn of the millennium, the focus has shifted to software-based acceleration of old workflows alongside the evolution of the ‘data scientist’ who augments automation by deriving actionable insights from the tons of ‘Dark data’ captured for so long without much of an analysis. Each unanalyzed seismic dataset often ran into hundreds of gigabytes and evolved into terabytes after the processing algorithms had analyzed them. www.oswindia.com
Deriving actionable insights ‘Easy oil’ is gone. Whatever remains needs strategic innovation at ever y phase of petrochemical business operations. Star ting from the upstream exploration and production at oil fields, continuing through the midstream sector’s distribution network up to the refineries of the downstream, engineering data analytics has become imperative for profitable sustainability. Th e t h re e p r i m a r y a re a s i n w h i c h t h e O & G s e c to r co u l d l e ve ra g e Engineering analytics and Artificial Intelligence (AI) are: i. Integrating large varieties and volumes of data in finding more crude oil with the most suited technology available ii. Contextualizing day-to-day operational data to reduce operational costs in labor, maintenance, and overheads without compromising on operational worker safety iii. Taking into consideration the constants at play, automating several non-critical decision making while reducing environmental impact Engineering analytics across the O&G lifecycle In the upstream, several O&G companies armed with seismic imaging technologies, geo-scientific and mechatronic sensors are accelerating digital innovation by replicating the oil field’s ‘Digital Twin’. Leveraging AI in the form of Deep learning and Machine learning algorithms applied on these digital replicas, oil companies are optimizing drilling activity accordingly by testing the drilling equipment’s digital counterpar t on the 3D seismic map created and run on simulation, rather than spending millions in drilling down to unviable sources. For example, data analytics could empower operators to compare real-time downhole drilling data with production data of adjacent wells to adjust drilling strategy, while also forecasting downhole tool failures and instantly customizing parameters based on real-time per formance compared with past performance or events. Moreover, the lift systems strewn with sensors that previously logged equipment parameters can now perceive and stall imminent failures with predictive and prescriptive maintenance capabilities augmented through advanced analytic algorithms. This is
Offshore World | 28 | April-May 2018
FEATURES how engineering analytics is helping increase reservoir throughput by extending equipment life and lowering the capital and high-risk intensive nature of the O&G production process. In the midstream, the pipeline network leading to the refineries no longer need to remain at the mercy of periodic manual checks. The sensors inside these pipes which only measured oil pressure, speed and temperature earlier, can now be upgraded to interpolate the corrosion coefficient of the pipeline while also factoring in satellite geo-imaging for structural integrity monitoring. Such advancements in the pre - emptive maintenance of the distribution net work would prevent not only leakages but also augment new-age solutions such as drone monitoring and central repor ting of any suppor t needed for quick and effective repairs. I n t h e d o w n s t re a m , t h e re f i n e r y a n d t h e e q u i p m e n t a re b e i n g retrofitted with various sensors and laser scanned in par ts to stitch together the refiner y ’s three - dimensional representation that can ser ve as the ‘Digital Twin’, just like the digital oilfield. This 3D refiner y map also augments health monitoring capabilities and predic tabilit y for the refiner y equipment that was previously quite disjointed and d e p e n d e d o n m a n u a l s u p e r v i s i o n . M o re o ve r, t o i m p ro ve wo r ke r produc tivit y and safet y, there is an increasing richness in immersive training content delivered through ‘Augmented Realit y (AR).’ Apar t from such technical aids for training, routine maintenance to- do’s are derived by engineering analytics and operationalized through smar tser vice apps on the field-ser vice operator’s handheld devices or AR glasses such as Microsoft HoloLens or Google Lens, while instruc ting them exac tly what to do and where. The Cloud or the Edge In order to gain enterprise-level predictability most of the companies are storing and processing the data collected on the cloud and comparing the results on region-wide, site-wide, enterprise-wide scale to identify the reasons why some assets are performing better than others. This is how they are optimizing the entire business value-chain. All such data collection and integration mandates superior data connectivity and processing power. While earlier this connection and processing was solely based on Cloud technology, the multiplicity and complexity of the current data sets have necessitated communication interfaces with higher speed, processing power, and dependability. Hence, many O&G Original Equipment Manufacturers (OEMs) are leveraging cloud only for development as the supervisor while deploying the end-processing programs on Edge Analytics as the executor. In order to supercharge edge analytics, many Oil Field Service (OFS) companies are coming forward to partner with end-to-end engineering service providers who have already earned the trust of industr y leaders like NVidia for their GPU-based development and deployment of Deep learning algorithms.
Challenges and the way forward A single smart oil well may generate up to 10 terabytes of data daily. With the standard O&G technology architec ture comprising an ETL (extract, translate and load) module coupled with a MDM (Master Data Management) system, a data warehouse, and an analytics tool, such vast quantities often remain under-analyzed for insights. Moreover, with several data transfer requirements between incompatible applications, data is often manually moved or converted through a human or digital intermediary. Such steps increase time, cost and the chances of erroneous analysis by limiting the identification and correction of wrong data sets. However, the primar y challenge that’s still decelerating the data analytics implementation in the O&G sector is the fragmentation and non-standardization of data collected by various proprietary technology and tools. Additionally, the problem also lies in the distributed data sets across the humongous O&G supply chain. Though, engineering analytics is the key to unlocking the actual value of digital transformation in the O&G sector, analytics alone is a not magic bullet capable of solving all the business and technical challenges at one go. Hence, with such distributed databases, blockchain could serve as a transparent ledger system where all these nodes will communicate with each other in an open yet secure way to enable efficient reuse of data with confidence in the system throughout the value chain. Likewise, investment in engineering analytics should be viewed as a business-led exercise, rather than a technology-led initiative. O&G leaders should be cautious about the fact that there are no ideal templates to follow in their quest to leverage data for automating lowimpact actionable insights. Rather than trying to digitize everything at a go, there should be a step-wise approach to digitization for data that should be tied to outcomes and business optimization. This includes a number of prerequisite steps such as installing sensors, leveraging existing information in historians, digitizing assets specially brownfield facilities with legacy designs using laser scans, digitizing maintenance procedures, building data infrastructure for harnessing enterprise data , asset monitoring & diagnostics strategies at asset/plant level and then linking the resultant data architecture to a customized and layered engineering analytic solution for impactful decision making. Nonetheless, insights and the resultant decisions can seldom transform the enterprise, unless they are efficiently backed up by robust technology architecture that can execute the decisions and proactively engage the employees through smart apps.
Offshore World | 29 | April-May 2018
Tarun Kant G l o b a l Te c h n o l o g y S o l u t i o n s L e a d e r f o r Engineering Soft ware QuEST Global Ser vices Email: NGovindR ajan@webershandwick .com www.oswindia.com
A 10.03 km long jetty pipeline was laid strategically for transfer of crude oil from smaller crude oil vessel that can berth at jetty, to the shore tanks of a shore-based refinery. The refinery also had Single Point Mooring (SPM) systems, which facilitates the berthing of Very Large Crude Carrier (VLCC). The import of crude oil in VLCC offers better economy of scale and it remained as the preferred mode for transportation, therefore, the jetty was rarely utilized. The subject telescopic jetty pipeline was of diameter 36/ 28 inches, grade API 5LX46 with a wall thickness of 9.52 mm. The pipeline system was considered non-piggable. The pipe was filled with either last pumped crude oil or sea water. During the idle period, the pipeline was kept pressurized. Within four years since commissioning, leakage from the pipeline was noticed near terminating point of the pipeline. Direct Assessment (DA) of the pipeline was arranged to assess the health integrity of the pipeline, while the pipeline was filled with low sulfur crude oil. The DA program, encompassing Internal Corrosion Direct Assessment (ICDA) and External Corrosion Direct Assessment (ECDA) and was conducted by an expert agency. The result of DA indicated severe internal corrosion, largely due to microbes presents both in seawater and filled fluid within the pipeline. DA recommended complete UT examination of the select pipeline section and adoption of immediate mitigation measures where the considerable loss in thickness is observed. Most importantly, owner’s decision to utilize DA as an integrity validation option for subject pipeline, allowed the owner to understand the critical corrosion behavior in the jetty line and avoid an imminent leak from happening!
Introduction and Problem Faced One of the coastal refineries in India has the facility of unloading crude oil cargo through Single Point Mooring (SPM) system. In addition to the SPM system, a jetty was constructed for unloading of crude oil cargo particularly during rough weather condition. The SPM system offers flexibility of mooring large tankers called VLCC (Very Large Crude Carrier) thus better economies of scale, so remains the preferred mode of transportation. At the jetty, only small tankers can be unloaded, so the jetty system although erected strategically was sparingly used. Accordingly, the subject jetty pipeline for transfer of crude to shore tanks through jetty largely remained idle and mostly remained filled either with high sulfur crude oil or with sea water. The telescopic jetty pipeline total length is 10.03 Km and diameter 36/ 28 inches. The pipe used was API 5LX46 grade with a nominal wall thickness of 9.52 mm. The pipeline was recently commissioned in early 2012. The pipeline was used for low bottom sediment and water crude oil (BS&W < 0.05 Vol %). The operating pressure was varying from 0.5-7.0 kg/Cm 2 and shut in pressure was 0.5 Kg/cm 2 . The pipeline was rarely used for regular transportation of crude. www.oswindia.com
The jetty pipeline system is considered non-piggable. The pipeline mostly remained shut in with either crude oil or with untreated sea water product. The shutdown time of the pipeline accounts for approximately 99 % of the total time since the pipeline came into existence. After nearly 4 years since commissioning, a leak was identified at the shore tank area near station limit valve of the pipeline. Prior to the leakage, the pipeline was shut in under pressure with stagnant untreated sea water for 2 years. The leak was repaired using an external leak clamp and subsequently, the pipeline was hydro-tested up to a pressure of 6 Kg/Cm 2 . During hydro-test period of 4 hours, no pressure drop was observed. Operating condition of the pipeline since commissioning has been summarized in Table 1. Process
Days
Pressure Testing (Seawater)
1
Flow with crude oil
9
Shut-in with crude oil
846
Shut-in with sea water
887
Table 1: Process conditions of the pipeline
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CASE STUDY
Integrity Validation Revealed Severe Internal Corrosion on a Crude Oil Jetty Non-Piggable Pipeline
CASE STUDY Sample (water)
pH
Dissolved O2 (ppm)
Alkalinity (ppm)
Pipeline Sea
Cl-
soluble Fe+2
Total Fe
7
5
6
6
S-2 (ppm)
(ppm)
(ppm)
(ppm)
80
<1000
0.4
1
0.1
63
10,000
0.1
0.2
0
Table 2: Chemistry of sea water and water in the pipeline under shut-in condition by colorimetric & titration tests Investigation and Corroboration The jetty pipeline section was considered not piggable due to multidiameter and also inaccessible regions at certain stretches due to Horizontal Directional Drilling (HDD) crossings of sea creek. It was decided to go ahead with the Direct Assessment (DA) integrity validation program due to its suitability for assessing the health of the pipeline section. The turnkey DA program, including Internal Corrosion Direct Assessment (ICDA) and External Corrosion Direct Assessment (ECDA)was undertaken by a group of experienced professionals as per NACE International Standard Practice. [1][2][3] Step 1-Pre Assessment of ICDA- Phenomenon of Microbial Influenced Corrosion (MIC In course of DA study, water samples were collected at the downstream end as a representative sample of the product within the pipeline. A water sample was also collected from the sea for representation. This was performed, as the line mostly remained shut in and filled with untreated sea water. The
Sample
A n o t h e r i n t e re s t i n g a n a e ro b i c g e n u s f o u n d w a s D e s u l f o t i g n u m (5%), which is a sulfur reducing bacteria and have similar metabolic characteristics as Desulfovibrio which is ex tensively studied as SRBs (Sulfur Reducing Bacteria). Moreover, Parcubacteria acts as an oxygen scavenger in absence of food source and further enhances the anaerobic conditions. [5][6][7][8][9][10][11][12] Under anaerobic conditions these two bacteria supplement for the metal degradation as detailed in Figure 2. Predominantly, several aerobic microorganisms were detected. Most of these species found under this environment are not considered to actively participate in causing corrosion but more so consume the oxygen by hydrogen oxidation (Hydrogenophaga) or sulphur oxidation (Thiobacillus). Pseduonomas & Sulfidobacter forms a gelatinous substance, which is known as Exopolymeric Substance (EPS). This EPS contains extracellular DNA, cyclopeptides and other organic material. [10][11][12]
Amount of 16S DNA (pg) in 1 gram of sample
Number of 16S molecules /g or /mL of sample
Calculated number of cells /mL
Water in Pipeline
1.69 x 10-4
244,620
8.2 x 104
Seawater
9.34 x 10-5
175,116
5.8 x 104
(Water)
Table 3: PCR analysis of seawater and water in the pipeline under shut-in condition. sample near the leak site indicated a low amount of sulfides (0.01 ppm). Microbial DNA analysis of pipeline water sample indicated large microbial community and the sample had the potential to cause Microbiologically Influenced Corrosion (MIC) through multiple mechanisms including sulfide production, acid production, biofilm formation as well as iron oxidation. DNA sequencing & qPCR (quantitative Polymerase Chain Reaction) was carried out as per NACE standard [4] for both the samples. Water chemistry was analyzed and results are detailed in Table 2. Moreover, the MIC activity was evaluated and is detailed in Table 3 and Figure 1. In the present scenario, around 21% of bacteria (Leptolinea, Desulfotignum, WS-6, Parcubac teria, Microgenomates, Thermovirga) are anaerobic. Moreover, Leptolinea is also capable of adapting to aerobic content (6%), this genus is methanogenic and grows on hydrocarbon degradation at near neutral pH level and moderate temperatures. [5][6][7]
This EPS forms biofilm, which provides anoxic environment beneath the layer and anaerobic bac teria grows under these circumstances and becomes the primar y factor for corrosion. These biofilms acts as differential-oxygen cell and may cause under deposit corrosion as shown in Figure 3. Local pH in these areas differ widely and hence make the estimation of corrosion growth difficult. [10][11][12] Step 2- Indirect Inspection of ICDA- Internal Corrosion Prediction Modeling (ICPM) For the purpose of ICDA, the pipeline was divided into 9 pipeline regions based on the presence of expander, reducer, navigational channel and HDD sections. The objective of step 2 of ICDA, that is Indirect Inspection step, was to determine the likelihood of internal corrosion and to predict the locations in the pipeline where internal corrosion would occur as a function of water and solids accumulation. [1][2][3] The temperature drop profile, pressure drop profile, the general corrosion rates, the localized corrosion rates, and the wall loss (%) of the jetty pipeline were calculated
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CASE STUDY MicrogenomatesSulfitobacter 1% Novosphingobium 1% 4% Parcubacteria 4% Candidate-division-
Thermovirga Others (<1%) 1% 1%
WS6 4% Desulfotignum 5% Leptolinea 6% Planctomyces 7%
Hydrogenophaga 29% Thiobacillus 18%
Porphyrobacter 8% Pseudomonas 11%
Figure 1: DNA analysis of water in the pipeline under shut-in condition.
Figure 1: DNA analysis of water in the pipeline under shut-in condition.
for four different scenarios i.e. the pipeline flowing with crude oil, shut-in with crude oil, shut-in with untreated seawater and hydro-testing with untreated seawater.
of a severe localized internal corrosion pit at one of the sites at chainage 8,671 m resulting in ~97% wall-loss which equates to a mere 0.36 mm remaining wall thickness with measured pit diameter as low as 3 mm.
The most probable locations (MPLâ&#x20AC;&#x2122;s) for water accumulation and solids deposition (based on two varying sizes of solid particles) were predicted for the pipeline as per Figure 4 and 5 respectively.
Step 4- Post Assessment of ICDA- Go Forward Plan
The average wall loss due to localized internal corrosion for the pipeline was calculated as 28.5% in the Indirect Inspection step. Eight assessment sites were chosen for detailed examination, i.e. step 3 of ICDA based on the Internal Corrosion Predictive Modeling (ICPM) results and the predicted MPLâ&#x20AC;&#x2122;s for solids and water accumulation in the subject pipeline. Step 3- Detailed Examination of ICDA- Onsite Direct Wall Thickness Measurements Out of the eight initial sites chosen for Detailed Examination, which had a high likelihood of internal corrosion, only two sites could be inspected and the locations of the other six sites were changed due to accessibility issues. The final eight Detailed Examination sites as per Table 4 that were assessed constitute < 0.1% of the total pipeline length and localized internal corrosion was confirmed in all eight sites including the detection www.oswindia.com
Using the most severe wall-loss obser ved among the eight Detailed Examination locations (i.e. 97% at 8,671 m), the subject pipeline has a calculated remaining life of 0.16 years or ~2 months and should be reassessed for internal corrosion in 0.08 years or ~1 month, respectively, since the date of completion of the on-site Detailed Examination of the pipeline. Notably, these calculations were performed assuming the corrosion growth rates observed from the Detailed Examination are linear since there was no baseline wall-thickness data available for this pipeline. Assuming linear corrosion growth rate, remains as the most conservative approach since the corrosion rates based on the identified root causes could be exponential. Hence, the remaining life of the subject pipeline could be lower than what has been calculated and are by no means an absolute timeline. Considering the severity of corrosion and criticality associated with the predicted remaining life of the susceptible section of the pipeline, as well as the environmental sensitiveness of the affected location,
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CASE STUDY
Figure 2: Reactions of SRB & Methanogens Figure2:
Reactions of SRB & Methanogens
immediate suitable measures were required to maintain the integrity of the pipeline. Moreover, complete UT measurement required at the MPLâ&#x20AC;&#x2122;s where considerable wall loss is likely and adoption of suitable mitigation measures for strengthening the section will be required. The location with 97% wall loss defect was immediately repaired by the owner as Figure2: Reactions of per ASME code B31.4.
corrosion threat as generally it is considered less corrosive compared to higher sulfur crude oils.
To minimize the risk for an environmental impact in an eco-sensitive zone, with a possibility of failure and crude spillover from the pipeline, the owner decided to displace the oil initially with seawater (which is SRB & Methanogens available in plenty) and subsequently dope the product with a suitable At the time of DA program, the pipeline was filled with low sulfur crude corrosion inhibitor. Simultaneously, a roadmap was drawn for thickness oil. The low sulfur crude oil was specially arranged to minimize the internal measurement / UT scan of assessable stretches of the pipeline.
Figure3: Under Deposit Corrosion- Consumption of oxygen by aerobic microbes & corrosion of Fe by anaerobic microbes in O2 depleted regions.
Figure 3: Under Under Deposit CorrosionConsumption of oxygenConsumption by aerobic microbes &of corrosion of Fe by microbes in O 2 depleted Figure3: Deposit Corrosionoxygen byanaerobic aerobic microbes & regions. corrosion
Fe by anaerobic microbes in O2 depleted regions. Offshore World | 33 | April-May 2018
of
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Water Layer Thickness (m) - 0.02 vol% Water Layer Thickness (m) - 0.113 vol% Inclination Angle (degree)
0.8 0.7
60
0.6
40
0.5 0.4
20
0.3
0
0.2 0.1 0
-20
0
2000
4000 6000 Distance (Jetty to Tank Farm) (m)
Figure 4: Calculated water accumulation in the pipeline withaccumulation inclination angle Figure 4: Calculated water
The pipeline environment is highly corrosive and the condition is worsening as the pipeline is under shut-in conditions during majority of its service life. The observed corrosion damage is very worrisome and hence some tough measures are being lined up for condition assessment, options are:
2.
Hydrostatic testing is an approved integrity validation option for inspection. The method was previously adopted, and the pipeline was hydro tested for 6 hours. The method is suitable for integrity assessment of a pipeline where the pipeline is operated at high pressure and defect actually fails during the destructive test. It is industrially accepted that pinholes may not be detected during hydrostatic testing. Hence, hydrostatic testing may not be an appropriate measure for integrity assessment of jetty line. Another option for inspec tion is magnetic stress tomography. Magnetic stress tomography is a technique where stress signatures on the pipeline are measured based on the pre-existing stresses on the material. Stress in a material aligns the atoms, which in turn creates their magnetic signature and specifies the stress levels. The technology is in its initial development phase. This method has mainly two major limitations i.e. a minimum axial dimension of
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8000
-40 10000
in the pipeline with inclination angle
Inspection Protocols:
1.
80
Inclination Angle (degree)
Water Layer Thickness (m)
CASE STUDY
the defect to be detected should be 10 mm and minimum operating stress of the pipeline shall be 40% of the Specific Minimum Yield Strength (SMYS). 3.
4.
As an immediate inspection protocol, condition assessment of the pipeline using external UT Inspection at MPLâ&#x20AC;&#x2122;s where predicted solid and water deposition is high as per ICDA. However, this may not providea complete representative of the pipeline length, though may provide a better insight into pipeline health. The internal corrosion pits detected, during Detailed Examination, were narrow and deep. These pits cannot be detected by a standard In Line Inspection (ILI) tools. Hence, a specialized UT-based ILI tool is required for the condition assessment of the pipeline.
A major hurdle for this inspection is the dual diameter nature of the pipeline. This pipeline also has an NRV (Non Return Valve) at one of the junctions where the pipeline is changing its diameter. This NRV is near to the shore and adjacent to tidal zone, which makes it fur ther difficult to remove the flapper of the NRV. Moreover, the piping, at the jetty also contains several 900 bends, which fur ther worsen the passage for an ILI tool. One of the ways to encounter the problem is to install a launcher and receiver for both of the diameters of the pipeline. Another way is to
Offshore World | 34 | April-May 2018
CASE STUDY
Solids Deposition (Vol %)
1.20E-05 1.00E-05
0
-10
8.00E-06 6.00E-06
-20
4.00E-06
-30
2.00E-06
0.00E+00
10
Elevation (m)
Solids deposition (150 microns) (%) Solids deposition (50 microns) (%) Elevation (m)
1.40E-05
0
2000
4000 6000 Distance (m)
Figure 5: Calculated solid deposition in the pipeline with inclination angle
8000
-40 10000
Figure 5: Calculated solid deposition in the pipeline with inclination angle
remove the NRV and use tethered intelligent pigs (robotic pigs) at both ends one by one. Even though these solutions could be feasible, however, several practical difficulties still exist for implementing these solutions. Mitigation Strategy Including Preservation of the Pipeline Some of the above -mentioned techniques may sound promising in this scenario, however, a full fledge Inline Inspec tion is needed for the complete inspection of the pipeline. After the assessment is complete, following methods may be used for fur ther degradation of the pipeline. 1.
2.
3.
Avoidance of seawater as far as possible. In mandatory conditions, where seawater is necessar y to be injected into the pipeline a suitable corrosion inhibitor and oxygen scavenger should be added to the system along with the sea water. Installation of a pigging facility to remove the deposited solid par ticles with a pigging frequenc y of 45 to 60 days. Based on ICDA deliverables, the Chloride ion concentration of the pipeline s u g g e s t s t h a t p i t t i n g r a t e i n c re a s e e x p o n e n t i a l l y a f te r t h i s time period. Injection of aggressive biocide at least once to remove the harmful microbes from the system. After removal of these microbes, it is necessar y to monitor the pipeline with onsite microbial testing, at ever y 30 days and DNA testing at least ever y 6 months or sooner if the microbial count increases.
Conclusion: Th e DA p ro g ra m p rov i d e d a s u i t a b l e i n s p e c t i o n m e t h o d o l o g y f o r h e a l t h a s s e s s m e nt o f t h e n o n - p i g g a b l e p i p e l i n e s. Th e p ro a c t i ve approach of ICDA to find susceptible corrosive locations based on I C P M w a s p ro ve n to b e e f f e c t i ve f o r t h e j e t t y p i p e l i n e. G e n e r a l c o r ro s i o n r a te s we re we l l w i t h i n t h e 1 0 % l i m i t a s p re d i c te d b y t h e m o d e l. B a s e d o n t h e N AC E s t a n d a rd p ro to co l s, t h e m e a s u re d wall loss values were within 10% limit of the estimated remaining wall loss for 7 out of the 8 dig inspec ted sites. However, the exac t predic tion of pitting corrosion wall loss depends on several other f a c t o r s t o o f o r w h i c h c o m p re h e n s i ve h i s t o r i c a l d a t a i s re q u i re d i n c l u d i n g i n s p e c t i o n a n d m o n i to r i n g i n f o r m at i o n w h i c h wa s n o t the case for the jett y pipeline. ICDA for the jett y p ipeline did prove the internal corrosion science by confirming the locations with the predic ted highest liquid and solid accumulation had the most severe measured internal corrosion. The corrosion was predominant due to ox ygen content in sea-water which was helping aerobic bac teria to grow and for biofilm to form. This biofilm was creating an anaerobic condition for bacteria allowing ac tive under deposit corrosion which was enhanced by the local pH variation. Most impor tantly, ownerâ&#x20AC;&#x2122;s decision to utilize DA as an integrit y validation option for non-piggable jett y pipeline, allowed the owner to understand the critical corrosion behavior in the jett y line and avoid an imminent leak from happening!
Offshore World | 35 | April-May 2018
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CASE STUDY Site
Chainage (m)
Nominal Wall Thickness (WT)
Least Measured WT
(mm)
(mm)
% Wall Loss Measured
% Wall Loss Predicted
1
8580
9.52
8.55
10.2
13.4
2
9487
9.74
8.8
9.7
14.1
3
9539
9.89
7.97
19.4
13.9
4
9582
9.73
8.51
12.5
14.1
5-A
8671
9.95
8.25
17.1
12.8
5-B
8671
12.03
0.36
97.0**
10.6
6
9867
9.52
7.7
19.1
13.4
7
9622
9.85
8.89
9.7
13.8
8
9719
9.99
8.56
14.3
13.7
Table 4: Wall Loss, Predicted vs Actual ** ICPM had predicted the highest likelihood of water and solid accumulation at this location where a pipeline bend and wall thickness transition was also found. Acknowledgement
9.
We express our sincere thanks to Dr. R. P. Badoni, Distinguished Professor, University of Petroleum & Engineering Studies (UPES), Dehradun, India and his team for guidance with microbial corrosion assessment that greatly improved the manuscript. References: 1. 1 N AC E S P 0 2 0 8 - 2 0 0 8 , I n t e r n a l Co r ro s i o n D i re c t A s s e s s m e n t Methodology for Liquid Petroleum Pipelines 2.
3.
4.
5.
6.
7.
8.
10.
Dennis Enning and Julia Garrelfs ,Corrosion of Iron by Sulfate Reducing Bacteria: New Views of an Old Problem Oil and Gas Pipelines: Integrity and Safety Handbook, Edited by R. Winston Revie
11.
Uhlig’s Corrosion Handbook, Edited by R. Winston Revie
12.
1Brenda J. Little, Jason S. Lee report no NRL/BC/7303-08-8 209
NACE SP0110-2010, Wet Gas Internal Corrosion Direct Assessment Methodology for Pipelines NACE SP0116-2016, Multiphase Flow Internal Corrosion Direc t Assessment (MP-ICDA) Methodology for Pipelines N A C E I n t e r n a t i o n a l T M 0 2 1 2 - 2 0 1 8 , D e t e c t i o n , Te s t i n g, a n d Evaluation of Microbiologically Influenced Corrosion on Internal Sur faces of Pipelines Katja Fichtel et al, Isolation of Sulfate -Reducing Bacteria from Sediments Above the Deep-Subseafloor Aquifer, Derya et al., Methanogenicarchaea and sulfate-reducing bacteria co-cultured on acetate: teamwork or coexistence?. J.B. Sawadogo, A.S. Traoré, and D. Dianou ,Relationships Between Methanogens and Sulfate-Reducing Bacteria During Acetate, Formate and Lactate Metabolism in Macrotermesbellicosus Termite Gut: Chuma Conlette Okoro et al.: Persistence of Halophylic Methanogens and Oil-Degrading Bacteria in an Offshore Oil-Producing Facility, Geomicrobiology
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Offshore World | 36 | April-May 2018
A. K. Tewari Executive Director (Operations) Indian Oil Corporation Limited
Deepak Agarwal Inspection Manager, Pipelines Head Office
Ashish Khera Director Allied Engineers Contact: akhera@alliedengineer.com
MARKETING INITIATIVE
MARKETING INITIATIVE
V-CONE FLOW METER SOLVES TEST SEPARATOR PROBLEMS FOR THE OIL & GAS INDUSTRY. Test separator applications
measurement systems to cope with the turndown but this can be time consuming, risky and costly when removing plates under system pressure.
Ideal for Measuring Wet Gas, Condensate and Dirty or Abrasive Flows With its advanced space-saving design, the new high accuracy V-Cone® FPSO flow meter is the ideal liquid, gas or steam measurement solution for cramped floating production, storage and offloading vessels operating in deep water or remote areas. Test separators are normally used when more than one well and field deliver fluid to the platform at the same time. It is impor tant to continuously monitor the oil, condensate, water and gas being delivered to the platform from each well. However, in the gas metering section of a test separator, liquid “carry over” is a well-known problem, especially when new wells are put on stream. Occasionally, when the well stream flow exceeds the capacity of the test separator, water, oil, agitated solids and other debris are carried over into the metering devices. As a result of this harsh treatment, orifice and conventional turbine meters have sometimes been found buckled or damaged— even when relocated somewhere downstream of the process. Other common problems with conventional meters include wax/ asphaltene build-up, sand / cavitation erosion and grease ingress/deposition from upstream valve lubrication. They contribute to inaccurate measurement, which in turn leads to an increase in total cost of ownership of the system. Also, when a well-test is being performed, there is usually higher than normal flow regimes/ velocities and the separator performance is reduced due to the meters’ over ranging. Generally, plate changes are needed on orifice designed
These heavy and bulky installations can incur weight and space penalties, a major consideration for today’s offshore platforms.
Why the V-Cone Flow meter is ideal for Test Separator Applications V-Cone flow meter offers an advanced differential pressure flow technology that acts as its own flow conditioner. This unique design enables the V-Cone flow meter to provide outstanding performance without the long lengths of upstream or downstream pipe runs usually required by other types of flow meters. This requirement for reduced straight pipe run results in significant space savings, especially on offshore platforms. For retrofit purposes, the V-Cone is simple to install. The V-Cone flow meter measures wet gas efficiently and provides a more stable, accurate result than other meters. There are no build-up problems with the V-Cone, unlike the orifice plate and some other flow meters. When two V-Cone flow meters are placed in parallel on a test separator gas run, the flow meters can cover the range that would require at least 10 orifice plates. The V-Cone provides an accuracy from ±0.5% and repeatability of ±0.1%. It comes in sizes from 1/2 inch to over 120 inches. It handles flow turndowns in excess of 10:1. High pressure meters are available. Corrosion resistant models in most materials are also available. Toshniwal Hyvac Pvt Ltd 267,Kilpauk Garden Road Chennai - 600010 Contact : +91 44 26445626 / 8983 Email: sales@toshniwal.net Website: www.toshniwal.net
Offshore World | 37 | April-May 2018
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NEWS
Crondall Appoints John Wishar t as NonExecutive Chairman
allows completely automated handling of material, without any human inter vention.
As a Chemical Engineer, John star ted his career briefly with BP before joining Genesis where he progressed through the leadership ranks, including establishing their Houston presence. After 11 years at Genesis, he transitioned through acquisitions to Aker Maritime, Coflexip and ultimately Technip and eventually leading the Americas business before returning to the UK to take on the role of Group Managing Direc tor at Noble D enton. Just over one year later, GL acquired Noble D enton and John remained in place for another 2 years, before heading up Energy for Lloyds Register where he led the acquisition of Senergy.
Commissioned in record time, and adhering to the highest standards, the plant has an ISO 9001:2015 cer tification for Quality Management System. With Health, Safety and Environment (HSE) being key priorities, the plant is equipped with all the necessar y measures for maintaining the highest levels of HSE and has trained its personnel in best HSE practices.
John is currently COO at Foresight Group International, which is a diversified business with interests in shipping, oil and gas, engineering, hospitality, retail, manufacturing, training and education.
The plant was officially inaugurated on Friday 18th May by Gulf Chairman, Sanjay Hinduja , together with his brother, Deeraj Hinduja and Shom Hinduja, Frank Rutten – Gulf Oil Vice President International, GOLIL Managing Director – Ravi Chawla and Sunil Jumbastaker, GOLIL VP Supply Chain.
Duncan Peace, Managing Director of Crondall Energy Consultants says:“ We a re d e l i g h te d t o we l c o m e J o h n t o t h e B o a rd. Th i s i s a m a j o r s te p i n t h e d e ve l o p m e n t o f Cro n d a l l a n d we l o o k f o r w a rd to wo r k i n g w i t h J o h n a s we c o n t i n u e t o g ro w t h e g ro u p. J o h n b r i n g s a we a l t h o f i n d u s t r y e x p e r i e n c e f ro m t h e o i l a n d g a s s e c to r, a n d h i s s p e c i f i c e x p e r t i s e i n t h e g ro w t h o f c o n s u l t i n g o rg a n i s a t i o n s w i l l b e o f p a r t i c u l a r v a l u e a s we e x p a n d t h e c o m p a n y o ve r t h e n e x t f e w ye a r s a n d c a p i t a l i s e o n t h e o p p o r t u n i t i e s w i t h i n a re j u ve n a te d i n d u s t r y ”.
Gulf Oil Inaugurates New Blending Plant in Chennai Gulf Oil Lubricants India Ltd, a Hinduja Group Company, has inaugurated its new blending plant facility in Chennai, India. Gulf Oil has emerged as the fastest-growing lubricants brand in India, and this plant will augment and strengthen the company’s plans for development both in India and other regions around the world. With a capacity of 50,000 KL per annum, the new plant boasts the most modern and advanced blending, filling and material handling facilities. The plant also houses the largest Gulf Oil R&D facility ever. Designed to develop the lubricants of the future, the R&D centre will help to add a fur ther competitive edge to the company’s products and to deliver superior customer value propositions. Some of the key technology points employed at the plant are the automatic batch blender, simultaneous metered blending, the drum decanting unit and piggable manifold. Most of the hi-tech plant systems have been custom-designed for Gulf Oil and manufactured by ABB, France. The Advanced Automated Storage and Retrieval System www.oswindia.com
The plant also boasts an environmentally-friendly design and has features, like rainwater har vesting, a sewage water treatment plant and the ability to run on solar power. Gulf Oil is in the process of applying for IGBC accreditation.
Odfjell Wins Contract from Equinor to Drill Production Wells O dfjell has secured an estimated $150m-200m contrac t from oil and gas company Equinor to drill six produc tion wells for the Fram and Askeladd licences on the Nor wegian continental shelf (NCS). Under the contrac t, the D eepsea Atlantic rig will be used to drill the wells. The par ties have also reached a master frame work agreement (MFA) that contains terms for future rig contrac ts on the NCS. Equinor Procurements senior vice -president Pål Eitrheim said: “We have reached a long-term agreement with standard terms that will ensure more efficient procurement processes for future assignments with O dfjell. Apar t from drilling ser vices, the scope of the contrac t includes casing running, slop treatment and cuttings handling, remote control vehicle (ROV ) and fuel. The rig will drill three ‘dual multilateral’ wells on the Fram field before proceeding to Askeladd to drill three produc tion wells. Apar t from drilling ser vices, the scope of the contrac t includes casing running, slop treatment and cuttings handling, remote control vehicle (ROV ) and fuel. The rig will drill three ‘dual multilateral’ wells on the Fram field before proceeding to Askeladd to drill three produc tion wells.
Offshore World | 38 | April-May 2018
Steven Lee, head of rig inspection services at Aqualis Offshore, which is part of Oslo-listed energy consulting group Aqualis ASA.
Canada will buy Kinder Morgan Canada Ltd.’s Trans Mountain oil pipeline and its controversial expansion project for C$4.5 billion ($3.5 billion) in a bid to ensure it gets built amid fierce opposition.
Aqualis Offshore has previously suppor ted Petronas in South East Asia, but this is the company’s first job in the Caspian region.
Finance Minister Bill Morneau and Natural Resources Minister Jim Carr announced the plan Tuesday in Ottawa. “It must be built and it will be built,” Morneau said. The deal, which includes the expansion, related pipeline and terminal assets, is expec ted to close in August. Construc tion will continue through the 2018 season, and the federal government will transfer it to one or more new owners when “appropriate.” Buying the pipeline outright had become increasingly likely after Prime Minister Justin Trudeau first pledged only to backstop it. “We are going to get that pipeline built,” Trudeau said Tuesday morning as he headed into a meeting with his cabinet. The purchase marks a stunning development for Trudeau’s government -- effectively nationalizing the country’s highest-profile infrastructure project until an operator can be found. The project has been beset by legal uncertainty and rising protests from environmental groups and the province of British Columbia. It will be a key test of Trudeau’s bid to
China’s CNOOC Sees Likely Start of Uganda Oil Field in 2021 CNOOC Ltd., the Chinese oil company developing Uganda’s crude finds with Total SA and Tullow Oil Plc, said produc tion at its Kingfisher field will probably star t in 2021. CNOOC is likely to bring Kingfisher on stream three years after making a final investment decision, expected later in 2018, according to Likun Kuang, finance manager at CNOOC Uganda Ltd. The field is one of several in the Alber tine Graben, an area estimated to hold 6.5 Bbbl of oil, where the government is targeting first production in 2020. Three years is a “reasonable” period to get the Kingfisher development ready, Kuang said in an inter view late Wednesday in the western town of Hoima. CNOOC plans to pump 40,000 bbl of crude a day from the field, feeding a planned 60,000-bpd refiner y as well as an expor t pipeline to the Tanzanian por t of Tanga.
balance the environment and the economy by backing the C$7.4 billion pipeline expansion while pushing a national carbon price to reduce greenhouse gas emissions.
CNOOC is developing Kingfisher on behalf of its par tners, France’s
Aqualis Offshore Secures its First Rig Inspection Deal in the Caspian
Azinam to Carry Out Drilling Campaign Offshore Namibia
Aqualis Offshore has been awarded a one-year service agreement with Petronas Carigali (Turkmenistan) Sdn. Bhd, to conduct drilling rig integrity inspection services for its drilling programs. Aqualis Offshore’s rig inspection work scope includes in depth surveys, including new-build rig acceptance surveys, acceptance trials and final integrated endurance tests. The work will be conducted by Aqualis Offshore’s dedicated team of rig inspection specialists, which consists of multi-disciplined engineers with decades of practical rig inspection experience to provide regulatory compliance and equipment operability assurance to rig owners and operators. “What we essentially do is to contribute towards ensuring safe and effective operational performance of drilling rigs. A strong rig inspection team will help reduce risks and increase operational uptime for the assets in question. We look forward to supporting Petronas again,” says
Total and London-based Tullow. Total is taking the lead at Tilenga, which will have a capacit y of 190,000 bpd.
Oil and gas exploration company Azinam has unveiled plans to undertake a multi-well drilling campaign offshore Namibia over the next 24 months. Through the drilling campaign, the company intends to test and verify its acreage across the Walvis Basin. Azinam holds stake in six licences across the majority of the Walvis basin, with working interests each ranging from 20% to 42.5%. The prospective resources contained in the licences are estimated to be more than ten billion barrels. The company noted that the licences are strategically positioned to allow access to the multiple play types within the basin. As well as an ex tensive 2D seismic database, Azinam has six modern 3D broadband seismic data sur veys covering an aggregate area of more than 13,000km2. Supported by a complete legacy well library, the database provides Azimuth with technical insights into the basin’s hydrocarbon potential.
Offshore World | 39 | April-May 2018
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NEWS
Canada to Buy Kinder’s Trans Mountain Pipeline for USD 3.5 Billion
PRODUCTS Oil Seals
Filters & Strainers
Klozure oil seals from Garlock Klozure are available in a wide variety of configurations to meet the requirements of major industries. Garlock Klozure oil seals are configured to meet industry requirements. MILLRIGHT materials are used on all elastomeric seals for superior bearing protection.
Cipriani Harrison’s filters and strainers are made from SS-304 and SS-316, are highly polished and come standard with FDA silicone seals. These filters and strainers consist of a housing with an inlet and outlet either inline or 90 o angle orientation. Inside the housing is the straining element that is fixed in such a way that the product flow is forced through it. This element consists of a backup tube and straining mesh. The housing with the element assembly inside it is then fitted between two stainless steel flanges by means of sanitary clamps and gaskets. These filters/strainers are 3A authorised.
Klozure oil seals are available in more than 50 different styles in sizes from ¼" to over 90", solid or split, metal-cased or all-rubber. For details contact: Garlock India Pvt Ltd Plot No: 21, "S" Block, MIDC Bhosari, Pune Maharashtra 411 026 Tel: 020-30616608 Fax: 91-020-30616699 E-mail: sales.india@garlock.com
For details contact: Cipriani Harrison Valves Pvt Ltd Sub Plot No: 2, B/s Margin Impex Ltd Nr Phase IV, GIDC Estate V U Nagar, Anand, Gujarat 388 121 Tel: 02692-235082, 235182 Fax: 91-02692-236385 E-mail: info@harrisonengineers.com
Pressure Relief Valves
Plug Valves
Cipriani Harrison’s pressure relief valves are made from forged SS-316L are highly polished and come standard with FDA EPDM seats and seals. These valves have self-draining machined bodies with a round shape that allows for a minimum resistance to flow. The valve body, yoke and actuator are assembled with camps enabling quick and easy assembly and disassembly. They are available in sizes 1-3” with sanitar y clamp and connections as standard. A manually adjustable spring closing force allows for a desired pressure rating being set. Once the line pressure reaches this set point the valve plug will lift and the pressure will be relieved through the side por t(s). These valves are 3A authorised.
Cipriani Harrison’s plug valves are made from SS-304L and SS-316L are highly polished and come standard with PTFE and FDA EPDM seals as well as stainless plugs. These valves are used in a variety of lowpressure sanitary applications. They are versatile and provide a full-unrestricted flow. Available in sizes 1-4” with sanitary clamp, Butt-weld end connections as standard. Offered in both two-way and three-way design all their plug valves have a long round handle that allows for smooth control and better leverage. A high degree of taper on the plug reduces the torque required to operate the valve. These valves are 3A authorised.
For details contact: Cipriani Harrison Valves Pvt Ltd Sub Plot No: 2, B/s Margin Impex Ltd Nr Phase IV, GIDC Estate V U Nager, Anand Gujarat 388 121 Tel: 02692-235082, 235182 Fax: 91-02692-236385 E-mail: info@harrisonengineers.com
For details contact: Cipriani Harrison Valves Pvt Ltd Sub Plot No: 2, B/s Margin Impex Ltd Nr Phase IV, GIDC Estate V U Nager, Anand Gujarat 388 121 Tel: 02692-235082, 235182 Fax: 91-02692-236385 E-mail: info@harrisonengineers.com
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Offshore World | 40 | April-May 2018
PRODUCTS Self-priming Centrifugal Pumps Rotocone Vacuum Dryer
Self-priming centrifugal pump has an excellent quick automatic priming action without foot valve. It automatically releases air during priming. Its dynamically balanced rotating parts ensure less vibration.This pump has better efficiency as per the international standard and available in bare, coupled, monoblock version. Pumps can be fitted with mechanical seal as per customer’s requirements. Also offered pump with trolley/trailer to move it from one place to another. It is applicable for transfer of clean or dirty neutral, acid or alkali liquids containing sand, mud or solids in suspension, clean or dirty low viscosity petroleum products or solvents, milk of lime, caustic soda and washing, cooling, smoke scrubbing and emergency duty. In waste treatment it pumps hot or corrosive wastewater containing sand, mud or solids in suspension, dosing neutralising liquids and pumping out settled sludge. In the construction industry it dewater excavation, canals or ponds, ground water dewatering with well point systems or drains, water supply from well or canals, hosing down concrete castings. For details contact: MBH Pumps (Gujarat) Pvt Ltd Plot No: 14, GIDC, Naroda Indl Estate Ahmedabad, Gujarat 382 330 Tel: 079-22823066, 22821018 Fax: 91-079-22821511 E-mail: mbhpumpsad1@sancharnet.in
Rotocone vacuum dryer is available in standard cGMP and customised models with SS-304/316/316L contact parts. Features low drying temperature, fast drying; easy to clean internal surface; continuous vacuum maintenance during process; dust filter is provided to filter solid particles; and cyclone separator to recover the solid particle. Also performs max function due to rotational movement and thereby reducing the processing time. Suitable size condenser; receiver is provided for solvent recovery. Available in batch capacities ranging from 50 to 3,000 kg, as per client’s requirements, depend on bulk density. For details contact: IPEC Engg Pvt Ltd Plot No: 5175, GIDC Ankleshwar Gujarat 393 002 Tel: 02646-221175 Telefax: 91-02646-225175 E-mail: md@ipecengg.com / marketing@ipecengg.com
Monitoring Solutions for Utilities LumaSense Technologies, Inc offers solutions for utilities. Industry professionals can get a first-hand look at sensors that connect to software platforms to gather, visualize, and analyze data to monitor and extend the life of their assets. LumaSense’s portfolio features a wide range of technologies suited for Transmission and Distribution (T&D) applications, including fiber optics, pyrometers, gas sensors and thermal imaging systems. For continuous, online monitoring of dissolved gases found in insulating oil of transformers and load tap changers, LumaSense suggests the SmartDGA system. This solution is cost-effective and based on proven, non-dispersive infrared (NDIR) technology to use industry standards to detect changes in gas rates, ratios and values. Implement automated, remote monitoring of substation assets using thermal imaging with the ThermalSpection 724 (TS724DV) system. Designed specifically for substations, this solution allows utilities to identify thermal abnormalities within electrical substations using high resolution cameras. LumaSense is the leader in Fiber Optic Technology, offering LumaSMART for transformer winding hot spot monitoring. This Fluropotic sensing system is the most advanced and reliable real-time monitoring solution available. For Sulphur Hexafloride (SF6) leak detection, the Innova 3731 provides highly reliable, high sensitivity SF6 area monitoring. This solution is based on highly accurate and repeatable Photoacoustic Spectroscopy (PAS) technology for an unmatched combination of performance and convenience. For details contact: LumaSense Inc Lorenzstraße 29 76135 Karlsruhe, Germany Tel: +49 (69) 97373198, +49 (0) 721 98 77 93 17 Fax: +49 (69) 97373167, +49 (0) 721 98 77 93 11 E-mail: s.schiepe@lumasenseinc.com www.oswindia.com
Offshore World | 41 | April-May 2018
PRODUCTS Flow Control Valves
Vortex Meter
Cipriani Harrison’s flow control valves are made from forged SS-316L are highly polished and come standard with FDA EPDM seats and seals. These valves have self-draining machined bodies with a round shape that allows for a minimum resistance to flow. The valve body, yoke and actuator are assembled with clamps enabling quick and easy assembly and disassembly. Available in sizes 1”-2.5” with sanitary clamp and Butt-weld end-connections as standard. The valve is operated by means of a manual handle which moves a conical plug gradually up or down. The plug has a calibrated profile that allows for fine flow control. The plug can be fixed in the desired position with a locking arrangement.
The VTX2 vor tex meter is used for flow and volumetric measurements of conductive and non-conductive fluids, gases and vapours in all industrial branches. An excellent flow meter designed for your process. It is ex tremely rugged, stable and maintenance -free, insensitive to pulsations, pressure bursts and temperature shock. It has excellent metrological characteristics and vibration compensation. Smar t electronics measurement of the operational state patented sensor for reliable sensing of vor texes. No re calibration required when replacing the sensor. Sensor design independent of nominal width. Highest possible application flexibility suited for high media temperatures.
For details contact: Cipriani Harrison Valves Pvt Ltd Sub Plot No: 2, B/s Margin Impex Ltd Nr Phase IV, GIDC Estate V U Nagar, Anand, Gujarat 388 121 Tel: 02692-235082, 235182 Fax: 91-02692-236385 E-mail: info@harrisonengineers.com
For details contact: Toshniwal Hyvac Pvt Ltd 267 Kilpauk Garden Road Chennai 600 010 Tel: 044-26448558, 26448983 Fax: 91-044-26441820 E-mail: sales@toshniwal.net
Mechanical Seals
Miniature Laser Sensors
Various pieces of rotary or rotating equipment, pumps in particular, depend on mechanical seals to control leakage. Mechanical seals are used anywhere that liquid and gases are transferred by rotating equipment. Pumps are one of the most widely sold pieces of equipment in industry, second only to electric motors. Although some of the small, inexpensive pumps are disposable (ie, automotive water pumps), most pumps require packing or mechanical seals to control leakage between the rotating elements and stationary housings. Klozure mechanical seals are available in both lip and face seal designs in four primary styles and a wide range of sizes. Key products include P/S-II lip seal, Syntron RP shaft seal, PK component seal, and GMP-I and GMP-II single and double cartridge seals. All provide sealing solutions for numerous applications in the chemical, pulp and paper, mining and power generation industries.
The new O300 miniature laser sensors with IO-Link by Baumer are the specialists for the reliable detection of very small objects and gaps. Thanks to a laser beam which focuses to within 0.1 mm and the high repeat accuracy of 0.1 mm, objects can be positioned with high precision and follow-up processes controlled exactly. Thanks to the extremely short response time of less than 0.1 ms, the sensor reliably detects even closely spaced objects, thus allowing fast processes and high throughput rates. A big advantage is the exact alignment of the laser beam to the fixing holes by design (qTarget). Thanks to qTarget, detection with pinpoint accuracy can be guaranteed over the entire series.
For details contact: Garlock India Pvt Ltd Plot No: 21, "S" Block, MIDC Bhosari, Pune, Maharashtra 411 026 Tel: 020-30616608 Fax: 91-020-30616699 E-mail: sales.india@garlock.com www.oswindia.com
For details contact: Baumer India Pvt Ltd Fourhum Centre, S No: 112/2/21, 112/2/64 & 112/2/72 Opp: RMD Sinhgad Institute Mumbai-Pune Highway, Warje Pune, Maharashtra 411 058 Tel: 020-66292400 Fax: 91-020-66292445 E-mail: sales.in@baumer.com
Offshore World | 42 | April-May 2018
PRODUCTS Coating Solutions
Borewell Submersible Pumps
Solenis offers its new Tapestry Yankee Coating Solutions to help tissue makers produce a consistently reliable Yankee coating while improving manufacturing performance and controlling operational costs. A reliable Yankee coating is essential for the efficient operation of a tissue machine. The Solenis Tapestry Yankee Coating Solutions include the most advanced chemistries on the market to optimize Yankee performance. Tapestry Yankee Coating Solutions enables the development of a coating that provides several benefits, including: Doctorability, Edge Control and Coating Uniformity. The resulting improvements to creping performance and tissue quality can ultimately impact a tissue millâ&#x20AC;&#x2122;s bottom line through enhanced productivity and improved product quality attributes such as softness and strength. In addition, a dependable coating is a key element in protecting tissue machinery.
CRI 200 mm (8") borewell submersible pumpsets - CR and CM Series are powered by water filled, rewindable submersible motor, which is suitable for continuous duty. The stator is wound with special water-proof synthetic film insulated copper winding wires and made up of low watt loss silicone steel laminations assembled under pressure and rigidly locked in SS stator shell. Specially designed thrust bearings (SS AISI-420 with graphite carbon) are used to withstand axial and down thrust loads with minimum wear and tear.
For details contact: Solenis 3 Beaver Valley Road, Suite 500 Wilmington, Delaware 19803 U.S.A. Tel: +1 866 337 1533 E-mail: smkukade@solenis.com / upatankar@solenis.com
For details contact: CRI Pumps Pvt Ltd 7/46-1 Keeranatham Road Saravanampatty Coimbatore Tamil Nadu 641 035 Tel: 0422-3027000 Fax: 91-0422-3027005 E-mail: corp@cripumps.com
Manual & Automated Cleaning Processes Consisting of four different combination options and used for cleaning heat exchangers, mycon GmbH's JetMaster system works based on high speed and cavitation effects. The system can be used manually or fully automatically. An automated JetMaster requires only around 180 litres of water per hour and no additives for a cleaning width of around 700 mm. Depending on the level of soiling, fully-automated cleaning of an exchanger area of around 300 m2 takes just six to ten operating hours. Thanks to automation, cleaning is available at any time and can be triggered at the touch of a button. The entire system is easy to adjust to any cleaning requirements using the integrated pneumatic and electric control unit. One control unit can serve multiple exchanger surfaces. mycon also supplies manual and automatic systems for cleaning tube bundle heat exchangers (TubeMaster system). The system can even polish the interior walls of the tubes, enabling significant energy savings and improved production processes. mycon provides also non-abrasive cleaning options for cleaning membrane walls. mycon's PowerMaster system cleans all steel and metal surfaces gently and cost-effectively without roughening. Removable plate heat exchangers are cleaned with mycon's PowerMaster system. For non-removable plate heat exchangers and inaccessible tube bundle heat exchangers, mycon offers flushing systems tailored to each individual case. The company also provides manual and automated solutions for these applications. mycon GmbH systems can also be observed under operating conditions. For details contact: mycon GmbH LorenzstraĂ&#x;e 29 76135 Karlsruhe, Germany Tel: +49 (521) 403090 Fax: +49 (521) 402482 E-mail: m.kueppershaus@mycon.info www.oswindia.com
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PRODUCTS Jet Self-priming Pumpsets
Centrifugal Monoblock Pumps
CRI jet self-priming pumpsets - CJS Series pump casing and ejector unit are designed carefully to give the best possible hydraulic efficiency and suction-lift characteristics. These pumpsets are powered by a totally enclosed fan-cooled AC induction motor, suitable for continuous duty. Motor stator is made of low watt-loss steel laminations assembled under pressure and rigidly locked in the frame. The varnish impregnated windings made of enamelled copper wire offer excellent resistance.
CRI centrifugal monoblock pumpsets - ACM Series are powered by a totally enclosed fan-cooled AC induction twopole motor. Motor stator is made of low watt-loss silicon steel laminations assembled under pressure and rigidly locked in the frame. The windings are of high-grade enamelled copper wire and are varnish impregnated. Construction of motor frame and usage of quality materials result in high per formance and low temperature rise thereby increasing the life cycle of the motor.
For details contact: CRI Pumps Pvt Ltd 7/46-1 Keeranatham Road Saravanampatty Coimbatore, Tamil Nadu 641 035 Tel: 0422-3027000 Fax: 91-0422-3027005 E-mail: corp@cripumps.com
For details contact: CRI Pumps Pvt Ltd 7/46-1 Keeranatham Road Saravanampatty Coimbatore Tamil Nadu 641 035 Tel: 0422-3027000 Fax: 91-0422-3027005 E-mail: corp@cripumps.com
Pipe & Tube Clamps
Quick Release Coupling
Excel Metal & Engg Industries offers wide range of instrumentation fitting and valves for use in diverse range of industries and are capable to provide their customers with best possible solutions to meet their various requirements. The production process followed is of higher standards with its modern production and quality assurance facilities where due attention is paid at every level with maximum resource utilization.
Excel Metal & Engg Industries offers wide range of instrumentation fitting and valves for use in diverse range of industries and are capable to provide their customers with best possible solutions to meet their various requirements. The production process followed is of higher standards with its modern production and quality assurance facilities where due attention is paid at every level with maximum resource utilization. Excel Metal & Engg Industries offers quick release coupling in SS, brass, MS, etc; 1/8 to 4 inch size; pressure rating up to 3,500, temperature rating up to 200 o C; lining: rubber, PTFE, nylon, etc; in Series NY, YNL, QC, KS, camlock.
Excel Metal & Engg Industries offers polymer and aluminium clamp bodies; light, heavy and twin Series pipe clamps and tube clamps; PP/aluminium/ hydraulic clamps; body material: steel plates and bolts. For details contact: Excel Metal & Engg Industries 177/181 J T Bldg, 3 rd Kumbharwada Lane, Mumbai 400 004 Tel: 022-23892476, 66394004 Fax: 91-022-23884109 E-mail: info@excelmetal.net / excelmetal@mtnl.net.in www.oswindia.com
For details contact: Excel Metal & Engg Industries 177/181 J T Bldg 3 rd Kumbharwada Lane Mumbai 400 004 Tel: 022-23892476, 66394004 Fax: 91-022-23884109 E-mail: info@excelmetal.net / excelmetal@mtnl.net.in
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PRODUCTS Turbine Flow Meter
CentrifugalRegenerativePumpsets
Turbine flow meters are precise and reliable measuring equipment, designed for varied applications. VTR flow meters can be installed even under the harshest application conditions including oil, petrochemical and chemical industries as well as other industrial sectors. The VTR Series consists of a rotor, the housing and the measurement pick-up. The flow of fluid activates the rotor. When the rotor blades interrupt the magnetic field lines of the pick-up system, the motion of the rotor is detected. As a result of the specific inner diameter, the turbine's revolutions are directly proportional to the flow.
CRI centrifugal regenerative pumpsets - PE/PS/NR Enr and Shine Series are power-driven by a totally enclosed fan cooled AC induction two-pole motor, suitable for continuous duty. Motor stator is made of low watt-loss silicon steel laminations assembled under pressure and rigidly locked in the frame. The windings are of highgrade enamelled copper wire and are varnish impregnated. Construction of motor frames and usage of quality materials result in high performance, noise-free operation and low temperature rise thereby increasing the life cycle of the motor. Non-self-priming model is with end suction and radial delivery.
For details contact: Bedaflow Systems Pvt Ltd W-7, Sector-11 Noida, Uttar Pradesh 201 301 Tel: 0120-43299 - 90 Fax: 91-0120-43299 - 20 E-mail: info@bedaflow.com
For details contact: CRI Pumps Pvt Ltd 7/46-1 Keeranatham Road Saravanampatty Coimbatore, Tamil Nadu 641 035 Tel: 0422-3027000 Fax: 91-0422-3027005 E-mail: corp@cripumps.com
Pump Monitoring System KSB offers a new pump monitoring system called KSB Guard. Net worked vibration and temperature sensors fitted direc tly to the pump make availabilit y at plant level transparent for the first time. The system ensures that changes in the operating behaviour of the machine are detec ted at an early stage, and maintenance work can be better planned, without having to be on site with the pump. KSB Guard is ideally suited for retrofitting. The sensor unit is attached to the bearing bracket or the drive lantern of the pump using a magnet and adhesive, and can be mounted during operation, with no need for changes to the machine. A battery unit, which is also supplied, provides self-sufficient power supply. The data, which is captured hourly, is transferred directly and wirelessly in encr ypted form to the KSB Cloud via a gateway for processing. Users can quer y the status data of all monitored pumps at any time and from any location using their mobile phone, a tablet or a PC, without having to be on site. For max coverage in the field, KSB Guard establishes a mesh network within the monitored pumps, thereby minimising the number of gateways required. For details contact: KSB Pumps Ltd Mumbai-Pune Road, Pimpri Pune, Maharashtra 411 018 Tel: 020-27101231 Fax: 91-020-27426000 E-mail: Yagnesh.Buch@ksb.com www.oswindia.com
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PRODUCTS Process Photometers
Vacuum Inlet Traps A broad range of high capacity vacuum inlet traps that protect vacuum pumps in manufacturing processes for HBLEDs and power semiconductors are available from Mass-Vac, Inc of USA. MV Multi-Trap Vacuum Inlet Traps are ideally suited for MOCVD, HVPE, GaN and ALGaN processes that generate high volumes of particulates and condensable byproducts in manufacturing HBLEDs and power semiconductors. Featuring a knock-down stage plus two stages of user-selectable filter elements, these vacuum inlet traps are capable of up to 2,500 in 3 of solids accumulation with >99% efficiency for particulates and condensables. Offered in 25.4 mm, 30.48 mm and 40.64 mm dia models, including a cooling option to facilitate removing condensables, MV Multi-Trap Vacuum Inlet Traps can be designed to accommodate different production processes and pump capacities to 2,000 CFM. They are available with activated alumina or charcoal filter elements for vapours, Sodasorb and other specialized elements for trapping other contaminants. For details contact: Mass-Vac, Inc 247 Rangeway Rd PO Box 359 No Billerica, MA 01862-0359, U.S.A. Tel: (978) 667-2393 Fax: (978) 671-0014 E-mail: drolph@massvac.com
Modern photometers enable accurate and reproducible concentration measurement by determining UV absorption, colour, NIR absorption, turbidity and cell growth. Due to their simple measuring principle, fast response time, low maintenance requirements and low dependence on or cross-sensitivity with other process parameters, they can be used in a huge variety of applications. Their hygienic design means that these process photometers are ideally suited for use in the food and life sciences industries. With an approval for use in hazardous areas, they can also be used in the chemical, and oil and gas industries. Inline measurement replaces time and labour intensive sampling and measurement in a lab and also prevents product contamination. This saves the customer time and money. All process photometers are connected to a Memograph CVM 50, which offers measured value acquisition and data management with FDA-compliant data security. Thanks to numerous communication protocols and interfaces, it can be seamlessly integrated into process control systems. For details contact: Endress+Hauser (India) Pvt Ltd 7B, 7 th Floor, Godrej One Pirojshanagar, Vikhroli (E) Mumbai 400 079 Tel: 022-30236100 Fax: 91-022-30236219 E-mail: info@in.endress.com
Point Level Safety Switch The Drexelbrook Safety IntelliPoint RF represents a significant advance in RF admittance reliability that addresses applications requiring safety instrumented functionality (SIF). The SIL IntelliPoint offers a full line of measurement probes to fit any process application where Safety Overfill Protection is required. This premium point level switch was designed to perform in the most challenging operating environments with extreme reliability while meeting API 2350 Overfill Protection Standards. The IntelliPoint RF level transmitterâ&#x20AC;&#x2122;s range of features and functions make it suitable for use in safety-related systems with requirements for functional safety for SIL2 (SIL3 with redundant switch). It is certified in accordance with IEC61508-2 and has worldwide hazardous area approvals (FM, FMc, ATEX and IECEX-Pending). IntelliPointâ&#x20AC;&#x2122;s electronics sense changes in the probe that simulate contact with the media or a floating roof, providing users with a method to ensure proper working performance without having to climb into the tank, and it automatically recognizes and ignores coatings to prevent false alarms. For details contact: AMETEK Drexelbrook 205 Keith Valley Road Horsham, PA 19044 U.S.A. Tel: 215-674-1234 Fax: 215-674-2731 E-mail: drexelbrook.info@ametek.com www.oswindia.com
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PRODUCTS Trace Hydrocarbon Analyser
Borehole Pumps
Incorporation of the latest advances in gas sensing technology and signal processing methodology, the new SERVOPRO NanoChrome revolutionises ultratrace purity measurements for the semiconductor industry.
MBH submersible CAST Series borehole pumps come with the best durability in the market. Due to their careful design, the pumps have the ability to resist sand and other abrasive material encountered in mining and dewatering applications. The seamless construction and the thickness of all AISI 316/AISI 304 casted SS hydraulic components grant a max resistance to wear and corrosion to all pumps range.
The new PED sensor technology enables sub-ppb measurement of H 2, CH 4, CO, CO 2 and NMHC; no consumables or fuel gas required; and enables unique total servomex solution for UHP gas analysis. For details contact: Spectris Technologies Pvt Ltd Plot No: A-168 MIDC Thane-Belapur Road Khairane Navi Mumbai 400 710 Tel: 022-39342700 E-mail: MEI_Sales@servomex.com
For details contact: MBH Pumps Plot No: 14, GIDC Indl Estate Naroda, Ahmedabad Gujarat 382 330 Tel: 079-22823066, 22821018 E-mail: marketing@mbhpumps.com
Platinum-cured Silicone Hose Reinforced with Polyester Braiding and SS-316 Helical Wire Imavacfit is platinum cured silicone hose reinforced with SS-316L helical wire and polyester braiding having better flexibility with high pressure resistance. Imavacfit is having high burst pressure rating along with high vacuum resistance compared to Imavac. The product is suitable in pressurized fluid transfer application. Imavacfit conforms to US FDA 21 CFR 117.2600 Food Grade Standard, USP Class VI and ISO 109931. It is cer tified by ROHS and Animal Origin Cer tification (free of animal derived material), free of restricted heavy metals. It is free of Phthalate/Bisphenol/Volatile Plasticizer. It has USFDA DMF accreditation #26201. Complete validation package available upon request. Imavacfit has high burst pressure resistance compared to Imafit and Imavac. It is designed for high vacuum rating applications. It has anti-static proper ties to dissipate static electrical charge makes it suitable for highly volatile flammable fluid transfer. It impar ts no taste and odour. It is lot traceable. Its temperature range is -80°C to 180°C. It is available with SS-316 L Tri-Clover end. It is sterilizable by Autoclave, Ethylene Oxide Gas and Gamma Radiation. For details contact: Ami Polymer Pvt Ltd 319 Mahesh Indl Estate, Opp: Silver Park Mira-Bhayander Road Mira Road (E), Thane Maharashtra 401 104 Tel: 022-28555107, 28555631, 28555914 E-mail: mktg@amipolymer.com www.oswindia.com
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PRODUCTS V -CONE FLOW METER
Oval Gear Meter
V-Cone flow meter is an advanced differential pressure instrument, which is ideal for use with liquid, steam or gas media in rugged conditions where accuracy, low maintenance and cost are important. With its DP bV-Cone is especially useful in tight-fit and retrofit installations. Features flow meter accuracy to +/-0.5% and repeatability to +/-0.1%; wide flow range; preconditions flow; requires minimal straight pipe; low head loss and maintenance; no recalibration; and long life
The measurement element of this positive displacement oval gear meters consists of two precision oval gears. The revolution can be sensed by a magnetic-field-controlled pulse generator, resulting in only two moving parts, ie, ovalwheels. These oval gear meters can be used for application of nearly all operating condition. Features very high/very low temperatures; low and extreme high viscosities; nominal diameter DN 4 to DN 400; direct measurement of volume respective of volumetric flowrate; measurement at high viscosities and high accuracy; and 2-wire technique.
For details contact: Toshniwal Hyvac Pvt Ltd 267 Kilpauk Garden Road Chennai 600 010 Tel: 044-26448558, 26448983 Fax: 91-044-26441820 E-mail: sales@toshniwal.net
For details contact: Toshniwal Hyvac Pvt Ltd 267 Kilpauk garden Road Chennai 600 010 Tel: 044-26445626, 26448983 E-mail: sales@toshnwial.net
Flow Meter
Mixproof Valves
The flow meter features built-in flow conditioning for superior accuracy. The VM V-Cone is the ideal new or retrofit flow meter for multiple clean and waste water treatment applications. The VM V-Cone System assures long-term performance because there are no moving parts to repair or replace. Once installed, the primary element rarely, if ever, needs to be removed from service. This leaves only the flow transmitter with the occasional recalibration over its lifetime. The V-Cone family of flow meters have a proven long life with installations exceeding 20 years without the need to be removed or re-calibrated. Features system accuracy of ±0.5% of rate; flow range: 10:1; installation typically 0-3 dia upstream and 0-1 dia downstream; no parts to wear so little maintenance required; and HART and Digital Protocols. For details contact: Toshniwal Hyvac Pvt Ltd 267 Kilpauk Garden Road Chennai 600 010 Tel: 044-2644 8558, 26448983 Fax: 91-044-26441820 E-mail: sales@toshniwal.net www.oswindia.com
Cipriani Harrison’s mixproof valves are made from forged/bar stock AISI 316L and 304L. Double seat valves are used in automated multiple routing systems with absolute confidence. Modern production processes demand simultaneous operation of product and cleaning cycles in order to maximise productivity and optimise operations. The construction of the valve guarantees that all products and cleaning liquids, in complex routing systems, remain separated, even in the event of seal failures. Available sizes ranges from 1-4”. Electronic control caps are available for communication/automation. For details contact: Cipriani Harrison Valves Pvt Ltd Sub Plot No: 2, B/s Margin Impex Ltd Nr Phase IV, GIDC Estate V U Nager, Anand Gujarat 388 121 Tel: 02692-235082, 235182 Fax: 91-02692-236385 E-mail: info@harrisonengineers.com
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EVENTS DIARY
events diary WGC 2018
4 th Annual IoT in Oil & Gas Conference
Date: 25-29 June 2018
Date: 18-19 September 2018
Venue: Walter E. Washington Convention Centre, USA
Venue: Hilton Americas-Houston, USA Event: The IoT in Oil & Gas 2018 Conference will focus on helping operators drive down costs and increase efficiencies.
Event: The World Gas Conference is the most impor tant global gas industr y gathering of influential leaders, policy-makers, buyers, sellers and exper ts. Conducted since 1931 by the International Gas Union (IGU), the triennial event aims to raise the voice of natural gas while offering timely updates on strategic, commercial and technical issues facing the entire gas value chain. The 27th World Gas Conference (WGC 2018) takes place in Washington DC from June 25-29 and offers the most comprehensive and diverse program to date for the natural gas industr y. For the first time ever this includes topics for professionals working in sectors including finance, trading, law, sustainability & renewables, policy & Government and many more. For details contact: Alice Murrie Tel: +44 20 7978 0775 Email: info@wgc2018.com
Over the past 3 years, thousands of oil and gas IT and OT leaders have met with the world’s leading solution providers to discuss how IoT technology can assist them in sur viving and thriving in the sustained low oil price environment. The 2018 program will see an evolution of topics, with more case studies as the technology becomes more embedded in the industr y. For details contact: MacKenzie Blankenship Tel: 855-869-4260 Email: mackenzie.blankenship@energyconferencenetwork.com
The Third UK Onshore Oil & Gas Summit
ADIPEC 2018
Date: 05 July 2018 Venue: Birmingham City Centre, UK Event: The Third UK Onshore Oil & Gas Summit will be reviewing results of test wells over the previous 12 months from both unconventional and conventional operations. Conference delegates will have the opportunity to hear from industry-leaders on the one-to-three year plan moving forward, in addition to learning more about the opportunities available to local companies and communities through the infrastructural supply-chain and the Shale Wealth Fund. The Summit will close out with a networking reception dedicated to promoting knowledge-sharing and relationship building with industry-leaders, government representatives, academics and stakeholders from industry and supply-chain providers from 17:00 19:30; with drinks and canapes provided.
Date: November 12 - 15, 2018
Other topics on the agenda will be the innovation of technologies that can address environmental concerns pertaining to air, noise and traffic pollution; as well as the safe treatment and disposal of flow back water. The summit will review Brexit’s impact on the UK’s oil and gas industry, as some experts warn that a ‘no deal’ scenario, resulting in the UK reverting to World Trade Organisation rules could almost double the industry’s cost of trade. For details contac t: Tel: 0161 376 9007 Email: info@openforumevents.co.uk
Venue: Central Plaza, Al Maa’red Hall, Abu Dhabi Event: Established in 1984, the Abu Dhabi International Petroleum Exhibition and Conference is a world-class business forum, where oil and gas professionals convene to engage in dialogue, create par tnerships, do business and identify solutions and strategies that will shape the industr y for the years ahead. ADIPEC has grown exponentially to become the world’s meeting point for oil and gas professionals. Today, over USD 10.34 billion of business is concluded during the exhibition, placing ADIPEC at the ver y hear t of international business of the global energy sector. Over 102,000 trade professionals attend ADIPEC, while 950+ industr y leading exper ts share their knowledge and understanding across the event’s expansive line -up of strategic and technical conference sessions. For details contact: Tel: +97124444909 Email: Adipec.sales@dmgeventsme.com
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BOOKSHELF
Oil and Gas Pipelines: Integrity and Safety Handbook (Hardcover) Author: R. Winston Revie (Editor) Publisher: Wiley Pages: 856 pages About Book: Oil and gas pipeline transport is used to supply energy to power our industries, fuel our cars, and heat and cool our homes. While an extensive pipeline network is an efficient and safe method of transporting petroleum and other products, several hazards and incidents, such as gas leaks and oil spills, have raised environmental and social concerns. Oil and Gas Pipelines: Integrity and Safety Handbook discusses the factors that affect the integrity of new and aging pipelines, public safety, and environmental protection. It covers the reliability of pipelines as affected by factors throughout the pipeline lifetime, ranging from design, manufacture, and welding to operation, inspection, monitoring, maintenance, and repair.
Offshore Pipelines (Hardcover) Author: Tian Ran Lin PhD, Boyun Guo, Shanhong Song Ph.D., Ali Ghalambor PhD, Jacob Chacko Publisher: Gulf Professional Publishing Pages: 304 pages About Book: Offshore Pipelines covers the full scope of pipeline development from pipeline designing, installing, and testing to operating. It gathers the authorsâ&#x20AC;&#x2122; experiences gained through years of designing, installing, testing, and operating submarine pipelines. The aim is to provide engineers and management personnel a guideline to achieve cost-effective management in their offshore and deepwater pipeline development and operations. The book is organized into three parts. Part I presents design practices used in developing submarine oil and gas pipelines and risers. Contents of this part include selection of pipe size, coating, and insulation. Part II provides guidelines for pipeline installations. It focuses on controlling bending stresses and pipe stability during laying pipelines. Part III deals with problems that occur during pipeline operations. Topics covered include pipeline testing and commissioning, flow assurance engineering, and pigging operations. This book is written primarily for new and experienced engineers and management personnel who work on oil and gas pipelines in offshore and deepwater. It can also be used as a reference for college students of undergraduate and graduate levels in Ocean Engineering, Mechanical Engineering, and Petroleum Engineering.
Subsea Pipeline Design, Analysis, and Installation (Hardcover) Author: Qiang Bai, Yong Bai Publisher: Gulf Professional Publishing Pages: 824 pages About Book: As deepwater wells are drilled to greater depths, pipeline engineers and designers are confronted with new problems such as water depth, weather conditions, ocean currents, equipment reliability, and well accessibility. Subsea Pipeline Design, Analysis and Installation is based on the authorsâ&#x20AC;&#x2122; 30 years of experience in offshore. The authors provide rigorous coverage of the entire spectrum of subjects in the discipline, from pipe installation and routing selection and planning to design, construction, and installation of pipelines in some of the harshest underwater environments around the world. All-inclusive, this must-have handbook covers the latest breakthroughs in subjects such as corrosion prevention, pipeline inspection, and welding, while offering an easyto-understand guide to new design codes currently followed in the United States, United Kingdom, Norway, and other countries.
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RNI No. MHENG/2003/13269. Date of Publication: 1st of every alternate month.