SUMMER INTERNSHIP

AT

INDIAN OIL CORPORATION LIMITED

TOPIC-

SELECTION OF PUMPS

FOR

CROSS COUNTRY PIPELINE SYSTEM

COMPILED BY:KRITIKA TYAGIB.Tech , 3rd year

IGDTUW , DELHI

CONTENT LIST

SERIAL NO.

TITLE PAGE NUMBER

1 Objective2 Acknowledgment3 Introduction to IOCL4 CHAPTER 1- Types of Pumps5 CHAPTER 2- Parts of Pumps6 CHAPTER 3- Important Characteristics7 CHAPTER 4- Characteristic Curves8 CHAPTER 5- Pump Selection9 CHAPTER 6- Splitting of parameters

10 CHAPTER 7- Pump Data Sheet

OBJECTIVE

In this report we shall first discuss the various types of pumps that can be manufactured . Further we narrow down our report to centrifugal pumps as these are generally used in oil industries. Indian Oil Corporation Limited uses centrifugal pump for various processes like pumping crude oil from offshore tankers to the port , pumping crude oil to oil segregation plants , pumping final product to various location all over the country . As we move further in the report we shall discuss the main characteristics that are considered while selection of pumps. To understand the main characteristics we need to know the working of centrifugal pumps and the physical aspects that it changes (pressure , velocity , head). The main characteristics are used to plot various graphs which help us in selection pumps while keeping our costs low and efficiency high . the final selection is done via pump data sheet which is available in API-610 .

The main objective of this report to understand the selection process that is followed by IOCL for various purchases.

ACKNOWLEDGMENT

“Words have never expressed human sentiments. This is only an attempt to express my deep gratitude which comes from my heart.”

It is great pleasures for me to express my deep feeling of gratitude to my respected guide Mr.K Santhanam (Dy.General Manager), for his great encouragement and constant support which provided desired moral and confidence to carry on my work.It is with profound gratitude that I wish to express my gratefulness to Mr. K Kittappa for his valuable and expert guidance and supervision in completion of this project work.I would also like to thank Mrs. Y Archana, Chief Manager, T&D for allowing us to undergo training in INDIAN OIL CORPORATION LIMITED (IOCL).

I am grateful to my parents for their lovable support. Last but not least I am thankful to my friends & other faculty members for their direct & indirect help for completion of this report.

KRITIKA TYAGI

INTRODUCTION TO IOCL

Indian Oil Corporation (IndianOil) is India's largest commercial enterprise, with a sales turnover of Rs. 4,50,756 crore and profits of Rs. 5,273 crore for the year 2014-15. It is also the leading Indian corporate in Fortune's prestigious 'Global 500' listing of the world's largest corporates, ranked at the 96th position for the year 2014. As India's flagship national oil company, with a 33,000-strong workforce , Indian Oil has been meeting India’s energy demands for over half a century. With a corporate vision to be 'The Energy of India' and to become 'A globally admired company,' Indian Oil's business interests straddle the entire hydrocarbon value-chain – from refining, pipeline transportation and marketing of petroleum products to exploration & production of crude oil & gas, marketing of natural gas and petrochemicals, besides forays into alternative energy and globalization of downstream operations.Having set up subsidiaries in Sri Lanka, Mauritius and the UAE, the Corporation is simultaneously scouting for new business opportunities in the energy markets of Asia and Africa. It has also formed about 20 joint ventures with reputed business partners from India and abroad to pursue diverse business interests.

BUSINESS

Indian Oil is India’s flagship Maharatna national oil company with business interests straddling the entire hydrocarbon value chain – from refining, pipeline transportation and marketing of petroleum products to Research & Development, Exploration & Production, marketing of natural gas and petrochemicals. By venturing into the Renewables and the Nuclear Energy, the company has grown and evolved itself from a pure petroleum refining and marketing company to a full-fledged energy company.

Having set up subsidiaries in Sri Lanka, Mauritius and the United Arab Emirates, IndianOil is simultaneously scouting for new business opportunities in the energy markets of Asia and Africa.

Born out of the vision of achieving self-reliance in oil refining and marketing for the nation, IndianOil has the proud possession of the world’s oldest running refinery at Digboi with a luminous legacy of more than 110 years and also the upcoming Paradip refinery, which when commissioned would be one of the most modern and complex refineries.

IndianOil Group (including two refineries of its subsidiary company Chennai Petroleum Corporation Ltd. (CPCL)) owns and operates 10 of India’s 22 refineries. The group refining capacity of 65.7 million metric tonnes per annum (MMTPA) or 1.31 million barrels per day (mb/d) is the largest among refining companies in India. It accounts for 30.5% share of national

refining capacity. On a stand-alone basis, the company owns and operates eight refineries with a capacity of 54.2 MMTPA (1.1 mb/d).

IndianOil reaches millions of people every day through an unmatched countrywide massive and ever-expanding infrastructure network to deliver Petroleum products. The network, comprising over 42,600 touch points as on 30.11.2014, was strengthened from 41,640 touches. Largest and most extensive network of retail outlets, numbering 24,403 (including 6,194 Kisan Seva Kendras), 136 depots and 6,376 consumer pumps for the convenience of large consumers, are some of the vital components of this network, ensuring availability of products and inventory at the doorstep of customers. The needs of domestic fuel (LPG) are fulfilled through 91 Bottling plants and 7,626 LPG distributors, serving over 86 million customers.

Continuing its thrust on reaching rural masses through Kisan Seva Kendras (KSKs) and LPG distributorships under Rajiv Gandhi Gramin LPG Vitaran Yojana (RGGLVY), IndianOil has continuously extended its reach to the rural India, with 6,194 KSKs and 1,867 RGGLVYs as on 31st November 2014. The KSKs and RGGLVs also represent a success story for Indian Oil in its efforts towards inclusive development in the rural hinterlands of India. The facilities at KSKs inter-alia include availability of seeds, pesticides, fertilizers, provisions, farm equipment, medicines, Nutan stoves, banking help including rural ATMs, communication etc, and all under one roof.

IndianOil places significant thrust on knowledge and research based growth and has a dedicated world class R&D center. The R&D center has 320 active patents to its credit as on 30th November 2014, of which 173 are active international patents. In the context of vagaries of the international crude oil prices and changing domestic pricing regime, IndianOil R&D is viewed as a key competitive advantage driver. Investment in proprietary research in lubricants, catalyst, refinery and pipelines operations, and product offerings are key thrust areas for Indian Oil. Research in new businesses, especially, petrochemicals and alternative energy is emerging a major focus area for Indian Oil.

IndianOil has established itself as a key player in petrochemicals with good market acceptability and occupies the second largest player in the domestic petrochemical market. Under the umbrella brand PROPEL, it offers a full products slate covering all the major segments of petrochemicals Viz. Linear Alkyl Benzene (LAB), Purified Terephthalic Acid (PTA), Paraxylene (PX), Mono Ethylene Glycol (MEG) & other glycols (DEG & TEG), Butene-1, Butadiene, Polypropylene (PP), Linear Low Density Polyethylene (LLDPE), High Density Polyethylene (HDPE) etc. Indian Oil has a market share of 22% in LAB, 16% in Polymers and 16% in Glycols. The company has also taken a lead in expanding petrochemicals business globally with exports to 21 new countries during 2013-14 taking the total to 66 countries with IndianOil’s footprint.

The gas business of the Corporation is intent upon leveraging the sizeable opportunities being presented by the country’s growing demand for gas. The company also plans to exploit the increased international gas sourcing opportunities brought on by the international unconventional gas revolution. The company also operates a unique concept of supplying LNG to small customers located away from the pipelines through ‘LNG at the Doorstep’, which has been highly successful. IndianOil’s 5 MMTPA LNG import terminal at Ennore will be the first

such terminal on the east coast and a gateway for the corporation to enter southern Indian gas market. This Terminal will be set up through a Joint Venture Company led by IndianOil. The Corporation is a partner in two joint ventures, namely, GSPL India Gasnet Ltd. And GSPL India Transco Ltd. with 26% equity participation for building of Mehsana-Bhatinda & Bhatinda- Jammu-Srinagar gas pipelines and Mallavaram-Bhopal-Bhilwara-Vijaypur gas pipeline, respectively.

IndianOil has been making continuous efforts to expand its E&P portfolio, both in domestic as well as overseas market. IndianOil presently has Participating Interest (PI) in 10 domestic and 7 overseas blocks. These blocks are in different stages of operations. Out of the 10 domestic blocks, IndianOil is operator with 100% PI in 2 onshore exploration blocks in Cambay basin. In the remaining 8 domestic blocks, it holds non-operating participating interest ranging from 20% to over 43%. Further, IndianOil holds non-operating participating interest ranging from 3.5% to 50% in the 7 overseas blocks located in 7 countries namely Libya, Gabon, Nigeria, Yemen, Venezuela, USA and Canada.

IndianOil’s foray into renewable energy is aimed not only towards diversification through inclusion of cleaner forms of energy in its portfolio but also for alleviating energy poverty and improving energy access at the 'base of the pyramid' in India. In its quest towards a greener world by offering sustainable and environment-friendly energy options, IndianOil is geared up to tap alternate energy sources such as wind, solar, hydrogen and bio-fuels. IndianOil aims to reduce the eco-footprints (carbon, water and waste) of its operations by exploiting these renewable energy resources.

With a view to expanding its cleaner energy portfolio, the company has set up a Joint Venture with NPCIL, namely, M/s NPCIL - IndianOil Nuclear Energy Corporation Limited (NINECL) for 2*700 MW Rajasthan Atomic Power Project 7&8 where IndianOil has 26% equity stake.

PIPELINES

Indian Oil Corporation Ltd. operates a network of 11,214 km long crude oil, petroleum product and gas pipelines with a capacity of 77.258 million metric tons per annum of oil and 10 million metric standard cubic meter per day of gas. Cross-country pipelines are globally recognized as the safest, cost-effective, energy-efficient and environment-friendly mode for transportation of crude oil and petroleum products.

The operational throughput of pipelines was recorded at 74.20 million metric tons during 2013-14. The offshore terminals of Indian Oil at Vadinar, Mundra and Paradip have handled 218 tankers including 128 VLCCs during the year. The multi-product pipelines successfully prepared to transport Euro IV grade fuels from refineries to marketing centers maintaining the high quality standards of products during transportation. Beginning with the first batch of Euro-IV MS grade quality fuel to National Capital Region in January, 2010, Euro IV grade quality fuels have been transported through the pipelines from refinery locations to the major metros for supply of these environment friendly products to the consumers as per the new emission norms.

IndianOil completed and commissioned the 290-km long Chennai-Bangalore Pipeline to position the petroleum products from Chennai Petroleum Corporation’s Manali refinery to Bangalore and surrounding areas in a cost-effective manner. Crude oil feed for the expansion of Panipat refinery to 15 million tons was arranged through the augmented Mundra-Panipat Pipeline. The augmentation project was commissioned during the year at a cost of Rs. 165 crore against approved cost of Rs. 205 crore.

Integrated crude oil handling facilities being provided at Paradip involves setting up of a second and third Single Point Mooring (SPM) and concomitant subsea pipelines. Crude oil blending application installed at Mundra has been an attractive solution for refineries with the ability to blend different crude types to provide a consistent and optimal feedstock to refinery operations. The online integrated crude oil blender facility is now being implemented at Vadinar crude oil terminal to enable the maximization of yields of higher value products.

Implementation of Paradip-Sambalpur-Raipur-Ranchi Pipeline, branch pipeline from Koyali-Sanganer Pipeline at Viramgam to Kandla will further strengthen the petroleum product delivery in central and western India in the coming years.

Nearly 14 pipeline projects are under implementation at an approved cost of over Rs. 6,700 crore. Upon completion, these projects would result in additional length of over 3,600 km and added capacity of 16 MMTPA. These include the 700 km Paradip-Haldia-Budge Budge-Kalyani-Durgapur LPG Pipeline, 295 km Sanganer-Bijwasan Naphtha Pipeline, Augmentation of PHBPL and five additional tanks at Paradip, 270 km branch pipeline from Patna to Motihari and Baitalpur, 120 km Cauvery Basin Refinery to Trichy Pipeline and 400 km Ennore-Trichy-Pondicherry LPG Pipeline.

CHAPTER 1Classification of pumps

OBJECTIVES:

1.1 Classification on the basis of Flow Pattern

1.2 Centrifugal Pumps

1.3 Reciprocating Pumps

a. Plunger Pumps

b. Diaphragm Pumps

c. Piston Pumps

d. Radial Piston Pumps

1.4 Classification of the basis of Service Liquid

1.5 Classification on the basis of Impeller type

1.6 Classification on the basis of the Mounting

1.7 Classification on the basis of different type of construction

1.8 Classification on the basis of different Position of Bearing

1.9 Classification on the basis of No. of stages

1.10 Classification on the basis of Position of Pump with respect to the Fluid

1.11 Classification on the basis of Splitting of casing

1.12 Types of centrifugal pump

1.13 Types of pumps available in the industry.

1.1 Pumps can be classified on the basis of Flow Pattern:

1 Intermittent-Positive Displacement Pumps. 2 Continuous-Roto-Dynamic or Turbo Pumps.

The two basic type of pumps are :-

1. Centrifugal pumps 2. Reciprocating pumps

1.2 Centrifugal Pumps

Centrifugal pumps are used to transport fluids by the conversion of rotational kinetic energy to the hydrodynamic energy of the fluid flow. The rotational energy typically comes from an engine or electric motor. The fluid enters the pump impeller along or near to the rotating axis and is accelerated by the impeller, flowing radially outward into a diffuser or volute chamber (casing), from where it exits.

Some properties of centrifugal pumps 1. The discharge is continuous and smooth. 2. It can handle large quantity of fluid. 3. It is used for large discharge through small heads. 4. Runs at high speed.

1.3 Reciprocating pumps

A reciprocating pump is a class of positive-displacement pumps which includes the piston pump, plunger pump and diaphragm pumps . It is often used where a relatively small quantity of liquid is to be handled and where delivery pressure is quite large. In reciprocating pumps, the chamber in which the liquid is trapped, is a stationary cylinder that contains the piston or plunger.

Some properties of reciprocating pumps :-

1. The discharge is fluctuating and pulsating. 2. Handles small quantity of liquid. 3. It is meant for small discharge at high heads. 4. runs at low speed .

Types of reciprocating pumps

1. Plunger pumps

2. Diaphragm pumps

3. Piston pumps 4. Radial piston pumps

.

1.4 Pumps can be classified on the basis of service liquid

1. Oil 2. Water3. Mud, Slurry

1.5 Pumps can be classified on the basis of type of impeller

1. Open2. Semi open3. Closed

1.6 Classification of pumps on the basis of mounting

1. Vertical

2. Horizontal

1.7 Classification of pumps based on different type of construction

1. Mono block-where motor is attached to shaft and the motor shaft is attached to the impeller.

2. Other types are where the motor and pump and coupled .

1.8 Classification based on position of bearing

1. OVERHELP -On one side of the pump there is the bearing and shaft . The other side is free unattached .

2. BETWEEN BEARING PUMPS - On both the sides of the pump there are bearings.

1.9 Classification on the basis of no. of stages

5. Single Stage (1 impeller)6. Multi Stage (more than 1 impeller)

1.10 Classification based on the position of pump with respect to fluid

7. Submerged pumps8. Externally placed pumps

1.11 Classification based on the type of splitting of casing

9. Axially split10. Radially

1.12 Types of Centrifugal Pumps

i. OH1 :- Foot-mounted single-stage overhung pumps shall be designated pump type OH1. (This type does not meet all the requirements of this International Standard)

ii. OH2 :-Centreline-mounted single-stage overhung pumps shall be designated pump type OH2. They have a single bearing housing to absorb all forces imposed upon the pump shaft and maintain rotor position during operation. The pumps are mounted on a base plate and are flexibly coupled to their drivers.

iii. OH3 :- Vertical in-line single-stage overhung pumps with separate bearing brackets shall be designated pump type OH3. They have a bearing housing integral with the pump to absorb all pump loads. The driver is mounted on a support integral to the pump. The pumps and their drivers are flexibly coupled.

iv. OH4 :- Rigidly coupled vertical in-line single-stage overhung pumps shall be designated pump type OH4. Rigidly coupled pumps have their shaft rigidly coupled to the driver shaft. (This type does not meet all the requirements of this International Standard.)

v. OH5 :- Close-coupled vertical in-line single-stage overhung pumps shall be designated pump type OH5. Close coupled pumps have their impellers mounted directly on the driver shaft. (This type does not meet all the requirements of this International Standard)

vi. OH6 :- High-speed integral gear-driven single-stage overhung pumps shall be designated pump type OH6. These pumps have a speed increasing gearbox integral with the pump. The impeller is mounted directly to the gearbox output shaft. There is no coupling between the gearbox and pump; however, the gearbox is flexibly coupled to its driver. The pumps may be oriented vertically or horizontally.

vii. BB1 :- Axially split one- and two-stage between-bearings pumps shall be designated pump type BB1.

viii. BB2 :- Radially split one- and two-stage between-bearings pumps shall be designated pump type BB2.

ix. BB3 :- Axially split multistage between-bearings pumps shall be designated pump type BB3.

x. BB4 :- Single-casing radially split multistage between-bearings pumps shall be designated pump type BB4. These pumps are also called ring-section pumps, segmental-ring pumps or tie-rod pumps. These pumps have a potential leakage path between each segment. (This type does not meet all the requirements of this International Standard.)

xi. BB5 :- Double-casing radially split multistage between-bearings pumps (barrel pumps) shall be designated pump type BB5.

xii. VS1 :- Wet pit, vertically suspended, single-casing diffuser pumps with discharge through the column shall be designated pump type VS1.

xiii. VS2 :- Wet pit, vertically suspended single-casing volute pumps with discharge through the column shall be designated pump type VS2.

xiv.VS3 :- Wet pit, vertically suspended, single-casing axial-flow pumps with discharge through the column shall be designated pump type VS3.

xv. VS4 :-Vertically suspended, single-casing volute line-shaft driven sump pumps shall be designated pump type VS4.

xvi.VS5 :- Vertically suspended cantilever sump pumps shall be designated pump type VS5.

xvii. VS6 :- Double-casing diffuser vertically suspended pumps shall be designated pump type VS6.

xviii. VS7 :- Double-casing volute vertically suspended pumps shall be designated pump type VS7.

1.13 Types of pumps used in oil industry

There are various types of pumps available in the market but only centrifugal pumps are usually used in the oil industry . Pumps can be used to pump oil, Slurry , Mud . Centrifugal pumps are also classified into various types of pumps they are given in the table below. The process of pump selection is a rigorous one . The API 610 is used for the process . API-610 is a document which has the standardized rules and regulations for the production of pumps. A Document called Pump Data sheet is used for the purchase of pumps by various companies. Pump data sheet consists of various different aspects of pump required by the purchaser .

CHAPTER 2

PARTS Of CENTRIFUGAL PUMPS

1. Casing:- The casing of a centrifugal pump serves to house the impeller and create a chamber for liquid to be pumped through. The drive pieces of a centrifugal pump also are housed in the casing.

2. Suction and Discharge Nozzles :-Built into the casing itself, the suction and discharge nozzles serve as ports for water to enter and exit from, respectively. Typically, suction nozzles are placed on the end of the pump and discharge nozzles are located on the top.

3. Seal Chamber and Stuffing Box :-Both seal chamber and stuffing box refer to the portion of the pump between the shaft and casing where the sealing mechanism of the pump is housed. Seal chambers utilize a mechanical seal, whereas stuffing boxes achieve the sealing purpose through some form of packing. Regardless of the method used, the chamber is used to prevent liquid from exiting the pump.

4. Bearing Housing:-The bearing housing is used to enclose and protect the shaft bearings, ensuring proper alignment. The housing will also include some type of method for lubricating the bearings and cooling the pump.

5. Impeller :-The main moving portion of the centrifugal pump. An impeller is a specially designed component critical for proper functioning of the pump. Depending on the suction type and mechanical construction of the pump, the actual design of the impeller may vary.

6. Shaft:- The shaft transfers the electrical or mechanical energy powering the pump directly to the impeller. In addition, the shaft is responsible for supporting any other moving parts on the pump. The shaft is responsible for a great deal of both energy transfer and structural support and therefore must be carefully machined.

7. Oil ring :- The bearings are most frequently oil bath or oil ring lubricated.

CHAPTER 3

IMPORTANT CHARACTERISTICS

OBJECTIVES

3.1 Working of Pumps

3.2 Head of a Pump

3.3 Importance of Head

3.4 Total Head

3.5 NPSHR

3.6 NPSHA

3.7 Volume Flow Rate

3.1 Working of a Pump

Centrifugal pumps are used to induce flow or raise pressure of a liquid. Its working is simple. At the heart of the system lies impeller. It has a series of curved vanes fitted inside the shroud plates. The impeller is always immersed in the water. When the impeller is made to rotate, it makes the fluid surrounding it also rotate. This imparts centrifugal force to the water particles, and water moves radially out.Since the rotational mechanical energy is transferred to the fluid, at the discharge side of the impeller, both the pressure and kinetic energy of the water will rise. At the suction side, water is getting displaced, so a negative pressure will be induced at the eye. Such a low pressure helps to suck fresh water stream into the system again, and this process continues. A rotodynamic or centrifugal pump is a dynamic device for increasing the pressure of liquid. In passing through the pump, the liquid receives energy from the rotating impeller. The liquid is accelerated circumferentially in the impeller, discharging into the casing at high velocity which is converted into pressure as effectively as possible.

3.2 Head of a Pump

It is assumed that a pump designed to move water clamped into a process line. There is a suction line and a discharge line, both running horizontally. Assuming that we are able to “move” the discharge line so it pumps straight up into the air. The pump is then turned on. Once the pump is running, it will move the fluid to some height measured in feet. That height to which the pump can raise the water to is its head.

3.3 Importance of Head

As the manufacturers do not know for what kind of fluid the purchaser requires the pump .The pump manufacturer's want to tell you how much head their pump's will produce but they don't know what type of water supply will be available, so how can they get around this. Ingeniously simple, they subtract the head available at the suction from the head produced at the discharge, they call this Total Head. Then it doesn't matter what the suction tank level is, they are telling you only what the pump can do regardless of the water supply pressure at the suction.

head is it is independent of the type of fluid being pumped (assuming the viscosity is relatively low and similar to water). Whether you’re pumping water or a heavy caustic solution, the head achieved will be the same. The pressure at the discharge of the pump, however, will be higher for the heavier solution. The relationship between head and pressure can be characterized by the following formula.

3.4 Total Head

Total Dynamic Head (TDH) is the total equivalent height that a fluid is to be pumped, taking into account friction losses in the pipe.

TDH = Static Height + Static Lift + Friction Loss

Static Height is the maximum height reached by the pipe after the pump (also known as the 'discharge head').

Static Lift is the height the water will rise before arriving at the pump (also known as the suction head). Friction Loss (or Head Loss).- this depends on the length of pipes and their diameter and the flow rate . Friction losses are different for different flow rates .

The relationship of head to pressure is expressed as

h=2.31p/SG

where

h = height of the fluid column above a reference point

p = pressure.

SG= Specific gravity

Net positive Suction head

NPSH is defined as the total suction head in feet of liquid (absolute at the pump centerline or impeller eye) less the vapor pressure (in feet) of the liquid being pumped.

3.5 Net positive suction head required

Net positive suction head required (NPSHR) is defined as the amount of NPSH required to move and accelerate the liquid from the pump suction into the pump itself. It is determined either by test or calculation by the pump manufacturer for the specific pump under consideration. NPSHR is a function of liquid geometry and the smoothness of the surface areas. For centrifugal pumps, other factors that control NPSHR are:

Type of Impeller Design of impeller Rotational Speed

3.6 Net positive suction head available

NPSHA must be equal to or greater than NPSHR. If this is not the case, cavitation or flashing may occur in the pump suction. Cavitation occurs when small vapor bubbles appear in the liquid because of a drop in pressure and then collapse rapidly with explosive force when the pressure is increased in the pump. Cavitation results in decreased efficiency, capacity, and head and can cause serious erosion of pump parts. Flashing causes the pump suction cavity to be filled with vapors and, as a result, the pump becomes vapor locked. This usually results in the pump freezing up, which is called pump seizure.

NPSHA is not a function of the pump itself but of the piping system for the pump. It can be calculated from

pA = atmospheric pressure

pva = liquid vapor pressure at pumping temperature.

NPSHA decreases with increases in liquid temperature and pipe friction losses. Because pipe friction losses vary as the square of the flow, NPSHA also varies as the square of the flow. Thus, NPSHA will be the lowest at the maximum flow requirement.

3.7 Volume flow rate (Q)

Also referred to as capacity, is the volume of liquid that travels through the pump in a given time (measured in gallons per minute or gpm). It defines the rate at which a pump can push fluid through the system. In some cases, the mass flow rate (m) is also used, which describes the mass through the pump over time.

CHAPTER 4

CHARACTERISTIC CURVES

OBJECTIVES

4.1 Performance Curve

4.2 The System Curve

4.3 Terms Used

8. Shut off Head

9. Cut off Head

10. Pump Runout

11. BHP

12. Impeller Trim

4.1 The performance or characteristic curve of the pump

The pump characteristic is normally described graphically by the manufacturer as a pump performance curve. The pump curve describes the relation between flow rate and head for the actual pump. Other important information for proper pump selection is also included - efficiency curves, NPSHr curve,pump curves for several impeller diameters and different speeds, and power consumption.

During a test, the total head that a centrifugal pump can develop is a function of the speed at which the impeller is turned and the diameter of the impeller. If a pump impeller is being turned at its rated speed and a valve on the discharge side of the pump is closed, it will develop a certain maximum head. Under these conditions, this head is read on a pressure gauge. The gauge reading translated into feet registers the height to which the pump is capable of elevating water. This is known as the “shut off head.” If the valve is slowly opened, the pressure gauge reading will fall as the flow increases, and this will continue until some point of maximum flow and minimum head is reached. If the total head being developed at any given rate of flow is plotted against the quantity of water being delivered, the result will be a performance curve for this particular pump at this particular speed.

Each pump will have its own maximum efficiency point. The best efficiency point (BEP) is the point of highest efficiency of the pump. All points to the right or left of the BEP have a lower efficiency.

Increasing the impeller diameter or speed increases the head and flow rate capacity - and the pump curve moves upwards.

The head capacity can be increased by connecting two or more pumps in series, or the flow rate capacity can be increased by connecting two or morepumps in parallel.The pump performance curves can made for trimmed impeller for same conditions

The units considered are different for different purposes . This curve is used to find the head flow of a trimmed impeller for a specific efficiency and flow rate . The impeller is trimmed to adjust to the requirement of a particular buyer.

4.2 The System Curve

A fluid flow system can in general be characterized with the System Curve - a graphical presentation of the Energy Equation.

The system head visualized in the System Curve is a function of the elevation - the static head in the system, and the major and minor losses and can be expressed as:

H=dh+h

where

H= System Head

dh= elevation (static) head - difference between inlet and outlet of the system

h= Head loss

Head loss = kq^2

Increasing the constant - k - by closing some valves, reducing the pipe size or similar - will increase the head loss and move the system curve upwards. The starting point for the curve - at no flow, will be the same.

Centrifugal pumps always pump somewhere on their curve, but should be selected to pump as close to the best efficiency point (B.E.P.) as possible. The B.E.P. will fall some where between 80% and 85% of the shut off head (maximum head).

4.3 Definitions

Shut off Head: The highest point the pump will lift liquid. At this point the pump will pump 0 gallons per minute.

Cut-off Head: The head at which the energy supplied by a pump and the energy required to move the liquid to a specified point are equal and no discharge at the desired point will occur.

Pump runout : is the maximum flow that can be developed by a centrifugal pump without damaging the pump. Centrifugal pumps must be designed and operated to be protected from the conditions of pump runout or operating at shutoff head.

BHP : Break Horse Power . The pump performance curve will give information on the brake horsepower (BHP) required to operate a pump (horsepower required at the pump shaft) at a given point on the performance curve. The brake horsepower curves run across the bottom of the pump performance curve usually sloping upward from left to right. These lines correspond to the performance curves above them (the top performance curve corresponds to the top BHP line and so on). Like the head-capacity curve, there is a brake horsepower curve for each different impeller trim.

Impeller Trims : Impeller trims or impeller diameter is measured in either inches or millimeters. Pump performance curves generally show performance for various impeller diameters or trims. Manufacturers will put several different trim curves on a pump performance curve to make pump specification easier, although this sometimes makes the pump performance curve more difficult to read. It is good practice to select a pump with an impeller that can be increased in size permitting a future increase in head and capacity.

CHAPTER 5

PUMP SELECTION

OBJECTIVES

5.1 Various factors considered in selection of pumps

5.2 Factors to be discussed in the report

5.3 Primary Factors

5.4 Secondary Factors

5.5 Cost

This generalized curve is not a detailed pump curve---it is simply a roadmap to tell you which specific pumps fit your flow and head requirements

5.1 Various Factors considered

13. Definition of the technological process outline and main process parameters, such as flow, pressure and temperature.

14. Determination of the required pumping services.

15. Complete description of the fluid to be handled in each pumping operation (type of fluid, temperature, density, viscosity, vapour pressure, solids in suspension, toxicity, volatility)

16. general layout of the plant and determination of available space in three dimensions;

17. general arrangement and dimension of the piping according to the recommended velocities for each fluid and type of pipe;

18. determination of elevation for suction and discharge points of vessels, relative to the centre line of the pump;

19. preliminary calculation of friction losses and plotting of system characteristic curves;

20. definition of the working parameters of the pump, namely capacity, head, suction and discharge pressures – taking into account any possibility of variations in pressure or temperature at different pumping conditions;

21. determination of any possible exceptional start, stop or running conditions;

22. determination of available NPSH (Net Positive Suction Head);

23. preliminary selection of the pump type, design, position, driver, type of sealing, and cooling of seal and bearings – if required;

24. establishing the type of drive unit (electric motor, steam turbine, etc) and its main operating parameters

5.2 Factors to be discussed in this report

Primary Factors are

25. Total Head

26. Flow Rate

27. Service

The Secondary factors are

28. NPSH

29. Purpose

30. Efficiency

31. Range

The ultimate deciding factor for a pump in the Oil pipeline Industry is the cost . The cost is to be minimized.

5.3 Primary Factor

The total head, suction lift and flow rate are dependent upon the piping system and the pump’s characteristics. The piping system and the pump interact to determine the operating point of the pump – flow rate and pressure.The pump cannot independently control these parameters. As the flow rate is increased the work to move each unit of water or total dynamic head the pump must produce increases.

5.3.1 Head

Total head and flow are the main criteria that are used to compare one pump with another or to select a centrifugal pump for an application. Total head is related to the discharge pressure of the pump.

Steps are

32. Determine the static head

33. Determine the Friction Head

34. Calculate the total Head

Select the pump based on the pump manufacturer’s catalog information using the total head and flow required as well as suitability to the application

5.3.2 Flow rate

Flow rate is directly proportional to speed or the velocity of the impeller . Changing the impeller diameter gives a proportional change in peripheral velocity which thus causes a change in the flow rate .

5.3.3 Services

By service it means whether it is operated continuously or weekly , quarterly , monthly etc.This is required as the pipelines might get clogged if not operated continuously and cleaning operations need to be done. For example In oil industry if a pipeline is not used continuously then grease and other materials are clogged inside the pipeline . Thus to reach the optimum flow warm crude oil is first transported through the pipes so that the grease and other substances would melt within days.

5.4 Secondary Factors

5.4.1 NPSH - Net positive suction head

For safe operation, NPSHA should exceed NPSHR (net positive suction head required) by more than 1m at the rated condition. As the NPSHR varies, depending on the head and flow, it is safer to select the margin at the end of the curve.

If the incoming liquid is at a pressure with insufficient margin above its vapour pressure, then vapour cavities or bubbles appear along the impeller vanes just behind the inlet edges. This phenomenon is known as cavitation and has three undesirable effects:

35. The collapsing cavitation bubbles can erode the vane surface, especially when pumping water-based liquids.

36. Noise and vibration are increased, with possible shortened seal and bearing life

37. The cavity areas will initially partially choke the impeller passages and reduce the pump performance. In extreme cases, total loss of pump developed head occurs

The three undesirable effects of cavitation described above begin at different values of NPSHA and generally there will be cavitation erosion before there is a noticeable loss of pump head. However for a consistent approach, manufacturers and industry standards, usually define the onset of cavitation as the value of NPSHR when there is a head drop of 3% compared with the head with cavitation free performance. At this point cavitation is present and prolonged operation at this point will usually lead to damage. It is usual therefore to apply a margin by which NPSHA should exceed NPSHR.

5.4.2 Purpose

That is the desired function of the pump . The function of the pump is same creating a head difference so that product can be transported . For example for irrigation a pump might be used to extract water from an underground well . For this the pump can be place in the ground immersed in water or if the net suction is sufficient it can be placed above ground and water can be pumped out .

5.4.3 Efficiency

Selecting a correct pumping plant not only will conserve valuable energy supplies but also will reduce total annual pumping costs. Inefficient pumping plants can increase costs dramatically.

The efficiency of a pump is a measure of the degree of its hydraulic and mechanical perfection. Pump efficiency is the ratio of the output water horsepower to the input shaft horsepower.

Some of the energy losses that result in lower efficiency are friction in the bearings that support the pump shaft, friction between the shaft and the packing in the stuffing box, unavoidable leakage between areas of high pressure and adjacent areas of low pressure inside the pump case, and the friction caused by the water moving across the metallic surfaces in the pump. There are also other losses of a more complex nature.

To conserve maximum energy the BEP should be between the rated point and the normal operating point.

The efficiency of a pump is determined by actual tests.The power required to turn the pump during the process of maximum flow and minimum head, you will note that the power is at a minimum for this typical centrifugal pump when there is no water being discharged from the pump and that the power required will gradually increase as the rate of flow increases and the head decreases. The maximum efficiency will be about midway between zero flow and maximum flow.

5.4.4 Range

The range is basically region of operation of that unit .It is the region where the efficiency is maximum according to our requirements .The lowest mark on the range corresponds to the NPSHR to avoid cavitation .running the pump outside the recommended operating range could and most likely will damage the pump by shortening bearing and seal life or even damage the shaft

5.5 Cost

A cost analysis of pumping will consider initial cost of capital investment, annual fixed cost and operating cost. All three costs are somewhat dependent on each other. The type of pumping equipment, size of pipelines, size of pumps and type of water supply affect not only the initial cost but also the fixed cost as well as the operating cost. For example, piping systems using large pipes may cost more but could allow the use of smaller horsepower pumps which cost less, require smaller power sources and cost less to operate than a piping system with small diameter pipe. The lowest priced system is not always the best buy, especially if the lower price means less efficient pumps. To get the most efficient pump, an analysis should be made of all pumping requirements.

CHAPTER 6

Splitting of parameters

OBJECTIVES

6.1 Why should we split the parameters

6.2 Pumps in parallel

6.3 Pumps in Series

6.1 Why should we split the parameter.

Using circulating pumps in parallel or series configurations can attain many economic and operational gains as opposed to using one large pump to supply a system’s pumping requirements.

Employing a combination of in-line pumps rather than base-mounted pumps to accomplish a pumping requirement eliminates the need for pump mounting pads, grouting, and shaft alignment. Equipment room floor space can be utilized for something else. The installed cost of two low-cost stock in-line pumps will be less than the installed cost of one large base-mounted pump, and can provide standby protection at no extra cost.

Often a designer will specify two pumps, each one capable of handling the entire load. In some cases, this may be essential, but on many installations, the cost of providing full standby capacity is prohibitive.

6.2 Pumps in parallel

energy efficient method of flow control, particularly for systems where static head is a high proportion of the total, is to install two or more pumps to operate in parallel. Variation of flow rate is achieved by switching on and off additional pumps to meet demand. The combined pump curve is obtained by adding the flow rates at a specific head. The head/flow rate curves for two and three pumps are shown in Figure

The system curve is usually not affected by the number of pumps that are running. For a system with a combination of static and friction head loss the operating point of the pumps on their performance curves moves to a higher head and hence lower flow rate per pump, as more pumps are started. It is also apparent that the flow rate with two pumps running is not double that of a single pump. If the system head were only static, then flow rate would be proportional to the number of pumps operating. It is possible to run pumps of different sizes in parallel

providing their closed valve heads are similar. By arranging different combinations of pumps running together, a larger number of different flow rates can be provided into the system.

6.2.1 WORKING

The total system flow divides into two parallel paths. The check valves prevent any flow short-circuiting, especially if only one pump runs. Since almost all installations of parallel pumps are with identical pumps, each pump will pump exactly one half of the total flow rate. Each pump will produce the same pressure head. Each pump will operate at the same point on its pump curve. In short, when both pumps are running, each pump supplies one-half of the total flow rate at the total system head.

If one of the pumps should fail, the other pump should still be able to supply enough flow to satisfy system demand, except in the worst weather.

6.2.2 Advantages of pump in series

Applying parallel pumps in a system can be a cost-effective solution when capacity requirements call for an unrealistically large pump and motor. Using parallel pumps can also reduce current surge during motor startup by staging two or more smaller pumps. This is a problem which may otherwise require expensive equipment such as electronic soft starters or part winding type motors. One of the most notable benefits of parallel pumps is the redundancy built into the system. If one pump were to fail in a two pump system, the second pump would not only continue to operate, but would also increase its output The beauty of parallel pump systems: If one pump were to fail, the second pump would run out on its curve until it crossed the system curve.

6.3 PUMPS IN SERIES

Putting your centrifugal pumps in series, or connected along a single line, will let you add the head from each together and meet your high head, low flow system requirements. This is because the fluid pressure increases as the continuous flow passes through each pump, much like how a multi-stage pump works.

Some things to consider when you connect pumps in series:

Both pumps must have the same width impeller or the difference in capacities (GPM or Cubic meters/hour.) could cause a cavitation problem if the first pump cannot supply enough liquid to the second pump.

Both pumps must run at the same speed (same reason). Be sure the casing of the second pump is strong enough to resist the higher pressure.

Higher strength material, ribbing, or extra bolting may be required. The stuffing box of the second pump will see the discharge pressure of the first pump.

You may need a high-pressure mechanical seal. Be sure both pumps are filled with liquid during start-up and operation. Start the second pump after the first pump is running.

After All the factor have been considered a Pump Data sheet is filled. The pump Data sheet is used by a purchaser to list its requirements and narrow down a few pumps .

CHAPTER 7PUMP DATA SHEET

OBJECTIVES

7.1 TERMS AND DEFINITIONS USED IN PUMP DATA SHEET

7.2 OPERATING CONDITIONS

7.3 SITE DATA

7.4 DRIVER TYPE

7.5 MOTOR DRIVER

7.6 LIQUID

7.7 MATERIAL

7.8 PERFORMANCE

7.9 UTILITY

7.10 CONSTRUCTION

7.11 SURFACE PREPARATION AND PAINT

7.12 HEATING AND COOLING

7.13 BEARINGS AND LUBRICATION

7.1 Terms and definitions used in pump data sheet

i. Barrel Pump :- horizontal pump of the double-casing type.ii. Best Efficiency Point (BEP) :- flow rate at which a pump achieves its highest

efficiency..iii. Critical Speed :- shaft rotational speed at which the rotor-bearing-support system is in a

state of resonance.iv. Dry Critical Speed :- rotor critical speed calculated assuming that there are no liquid

effects, that the rotor is supported only at its bearings and that the bearings are of infinite stiffness.

v. Wet Critical Speed :-rotor critical speed calculated considering the additional support and damping produced by the action of the pumped liquid within internal running

clearances at the operating conditions and allowing for flexibility and damping within the bearings.

vi. Suction Pressure max :- highest suction pressure to which the pump is subjected during operation

vii. NPSH ,Net Pressure suction Head :-total absolute suction pressure determined at the suction nozzle and referred to the datum elevation, minus the vapour pressure of the liquid

viii. NPSHA , Net Pressure Suction Head Available :- NPSH determined by the purchaser for the pumping system with the liquid at the rated flow and normal pumping temperature.

ix. Rated flow :The pump inlet flow, which will be measured, and guaranteed, when the pump is tested. Rated flow is associated with rated differential head for rotodynamic pumps, and rated outlet pressure for positive displacement pumps.

x. Suction Pressure: Operation of the pump creates suction (a lower pressure) at the suction side so that fluid can enter the pump through the inlet. Pump operation also causes higher pressure at the discharge side by forcing the fluid out at the outlet.

xi. Rated Suction pressure :Rated suction pressure would be the suction pressure needed when the pump is discharging its rated flow.

xii. Discharge Pressure: Discharge pressure describes the pressure of a liquid as it leaves a pump.

xiii. Differential Pressure. it is the amount of head that is added to the system .Differential pressure is the pressure increase provided by the pump between the pump inlet and outlet. It is measured as the difference between the pressure at the pump’s discharge flange and the suction flange.

xiv.NPSHA :The absolute pressure at the suction port of the pump.NPSHA MUST be greater than NPSHR for the pump system to operate without cavitating. NPSHA = HA ± HZ - HF + HV - HVP HA=The absolute pressure on the surface of the liquid in the supply tank HZ=The vertical distance between the surface of the liquid in the supply tank and the centerline of the pump HF=Friction losses in the suction piping HV=Velocity head at the pump suction port HP=Absolute vapor pressure of the liquid at the pumping temperature .

xv. Area classification : method of analysing and classifying the environment where explosive gas atmospheres may occur so as to facilitate the proper selection and installation of equipment to be used safely in that environment

xvi.Class : The Class defines the general nature (or properties) of the hazardous material in the surrounding atmosphere which may or may not be in sufficient quantities a. Class I—Locations in which flammable gases or vapors may or may not be in sufficient quantities to produce explosive or ignitable mixtures. b. Class II—Locations in which combustible dusts (either in suspension, intermittently, or periodically) may or may not be in sufficient quantities to produce explosive or ignitable mixtures.

c. Class III—Locations in which ignitable fibers may or may not be in sufficient quantities to produce explosive or ignitable mixtures.

xvii. Division—The Division defines the probability of the hazardous material being able to produce an explosive or ignitable mixture based upon its presence. a. Division 1 indicates that the hazardous material has a high probability of producing an explosive or ignitable mixture due to it being present continuously, intermittently, or periodically or from the equipment itself under normal operating conditions. b. Division 2 indicates that the hazardous material has a low probability of producing an explosive or ignitable mixture and is present only during abnormal conditions for a short period of time

xviii. Group—The Group defines the type of hazardous material in the surrounding atmosphere. Groups A, B, C, and D are for gases (Class I only) while groups E, F, and G are for dusts and flyings (Class II or III). a. Group A—Atmospheres containing acetylene. b. Group B—Atmospheres containing a flammable gas, flammable liquid-produced vapor, or combustible liquid-produced vapor whose MESG is less than 0.45 mm or MIC ratio is less than 0.40. c. Group C—Atmospheres containing a flammable gas, flammable liquid-produced vapor, or combustible liquid-produced vapor whose MESG is greater than 0.45 mm but less than 0.75 mm or MIC ratio is greater than 0.40 but less than 0.80. Typical gases include ethyl either, ethylene, acetaldehyde, and cyclopropane. d. Group D—Atmospheres containing a flammable gas, flammable liquid-produced vapor, or combustible liquid-produced vapor whose MESE is greater than 0.75 mm or MIC ration is greater than 0.80. Typical gases include acetone, ammonia, benzene, butane, ethanol, gasoline, methane, natural gas, naphtha, and propane. e. Group E—Atmospheres containing combustible metal dusts such as aluminum, magnesium, and their commercial alloys. f. Group F—Atmospheres containing combustible carbonaceous dusts with 8% or more trapped volatiles such as carbon black, coal, or coke dust. g. Group G—Atmospheres containing combustible dusts not included in Group E or Group F. Typical dusts include flour, starch, grain, wood, plastic, and chemical

xix.Location of pump : location of pumps are based on the application . Typical applications include I. Water disposal II. Secondary recovery III. Glycol dewatering IV. Amine sweetening V. Chemical injection VI. Crude transfer VII. Fire protection VIII. Pipeline Transfer IX. Produced water disposal X. Secondary recovery (water flood) XI. Chemical injection Glycol dehydration

XII. Well servicing XIII. Blow out preventer XIV. Liquefied natural gas XV. Lean oil circulation XVI. Closed drain pump-out XVII. Knockout drum pump-out

xx. Driver Type : can be and induction motor or a steam turbine or other type of power sources

xxi.Full Load : Full Load is the expected performance of the motor at the rated or nameplate hp. Maximum Load is often also referred to as service factor amps or max amps

xxii. Locked Motor AMPS : Locked Rotor Current" also called LRA which stands for Locked Rotor Amps, is commonly found on electric motor nameplates. Locked Rotor essentially means the motor is not turning. The current or amps in this case have to do with the amount of electrical energy required to start the motor. At the instant the motor is switched on, it is not turning, and draws the maximum current. As the motor starts to turn, the current goes down. This required energy is much greater than the Full Load Amps or Running Amps, which is the current drawn when the motor is running at normal speed under full load. The current required to start the motor will depend on the type of motor as well as the specified design voltage required for the motor, typically the higher the voltage, the lower the required amperage or current.

xxiii. Radial Bearing : Radial bearings accommodate loads that are predominantly perpendicular to the shaft. The bearings are typically classified by the type of rolling element and shape of the raceways.

xxiv. Classfication of Flammable Liquid : a flash point below 100 degrees Fahrenheit (38 degrees Celsius). Less-flammable liquids (with a flashpoint between 100 degrees and 200 degrees Fahrenheit) are defined as combustible liquids.

xxv. Flash Point : Flash point is the lowest temperature at which a liquid can form an ignitable mixture in air near the surface of the liquid. The lower the flash point, the easier it is to ignite the material.

xxvi. Chloride conc : The concentration of these salts in the crude oil depends on the oil field from which the crude is extracted, but it is usually present within the range of 3 to 300 pounds per barrel. In heavy crude oils this value tends to be higher.

xxvii. H2S conc : Crude oils usually contain sulfides that can cause corrosion at high temperatures. This is called sulfidation. It is a well-known corrosion in different units in oil refineries. The amount of total sulfur in a crude oil depends on the type of oil field and it varies from 0.05 percent to 14 percent. Of course, sulfur values as low as 0.2 percent are enough to create sulfidation corrosion in plain steels and low alloy steels. These kinds of steels are usually proposed to be used in several parts of refinery units.

xxviii. Pump Performance Curve : The pump characteristic is normally described graphically by the manufacturer as a pump performance curve. The pump curve describes the relation between flow rate and head for the actual pump.

xxix. Impeller Diameter : The calculations are based on the affinity laws which in turn are derived from a dimensionless analysis of three important parameters that describe pump performance . If the speed (revolutions per minute) of the impeller remains the same then the larger the impeller diameter the higher the generated head. Note that as you increase the diameter of the impeller the tip speed at the outer edge of the impeller increases commensurately. However, the total energy imparted to the liquid as the diameter increases goes up by the square of the diameter increase. This can be understood by the fact that the liquid's energy is a function of its velocity and the velocity accelerates as the liquid passes through the impeller. A wider diameter impeller accelerates the liquid to a final exit velocity greater than the proportional increase in the diameter.

xxx. Maximum allowable Pressure : MAWP being the maximum pressure based on the design codes that the weakest component of a Pressure vessel can handle. Commonly standard wall thickness components are used in fabricating pressurized equipment, and hence are able to withstand pressures above their design pressure.

xxxi. Design Pressure : The most severe condition of coincident internal or external pressure and temperature (minimum or maximum) expected during service”.

7.2 OPERATING CONDITIONS

PARAMETER GIVEN BY REQUIREMENTSFlow, Rated Purchaser Rated flow is associated with rated

differential head for rotodynamic pumps, and rated outlet pressure for positive displacement pumps.

Suction pressure max. Purchaser Some factor like pump's suction flange which limits suction pressure to the given maximum value.

Suction Pressure rated Purchaser It depends on rated flow .Discharge Pressure Discharge pressure depends on the

pressure available on the suction side of the pump

Differential Pressure Determined by evaluating all pressure (or head) losses from the liquid level in the receiver through all piping and components of the system and back to the receiver.

NPSHA Purchaser It depends on five factors1)The absolute pressure on the surface of the liquid in the supply tank.2)The vertical distance between the surface of the liquid in the supply tank and the centerline of the pump3)Friction losses in the suction piping4)Velocity head at the pump suction port5)Absolute vapor pressure of the liquid at the pumping temperature

Service: continuous/intermittent/ parallel operations required

Purchaser The type of service depends on the requirement of the product , the cost of operation that is incurred , the eeficiency.

7.3 SITE DATAPARAMETER GIVENLocation: Purchaser Based on the application of pump and the

location of the plant.Altitude Purchaser Based on location of plant.Barometer Purchaser Based on location of plantRange of ambient temperature

Purchaser Based on location of plant

Relative Humidity Purchaser Based on location of plantUsual Conditions1)Dust

Purchaser Based on location of plant

2)FumesELECTRICAL CLASSIFICATION AREAClass Purchaser It depends on the general nature of the

explosive material . It might be1)gas or vapour2)Dusts4)Fiber

Group Purchaser Depends on the type of hazardous material in the surrounding atmosphere. Groups A, B, C, and D are for gases (Class I only) while groups E, F, and G are for dusts and flyings (Class II or III).

Division Purchaser Depends on the probability of the hazardous material being able to produce an explosive or ignitable mixture based upon its presence.

7.4 DRIVER TYPE

PARAMETER GIVEN BY REQUIREMENTDriver type Purchaser The types of drives that can be used are

turbines , induction motor , engines etc.

7.5 MOTOR DRIVER

PARAMETER GIVEN BY REQUIREMENTPower Manufacturer The power at which the motor driver

operates and provides the required impeller speed , head , flow rate.

Frame Manufacturer The Frame type of the motor driver .VOLTS/PHASE/HERTZ Manufacturer The specifications of electricity supply

required by the motor.Minimum Starting Voltage Manufacturer The voltage below which the motor will

not start.Insulation Manufacturer The insulation of motor from the liquid

being used.Temperature rise manufacturer The rise in temperature in the motor due

the working of the motor driver , the friction when coupled.

Full Load AMPS Manufacturer expected performance of the motor at the rated or nameplate hp.

LOCKED rotor AMPS Manufacturer depend on the type of motor as well as the specified design voltage required for the motor

Starting Method Manufacturer The motor driver is and electrical device it is important to mention the starting method . Is it battery operated or another electrical supply is attached

Radial Bearing Type Manufacturer The type of bearings used to reduce the friction . These are lubricated .

7.6 LIQUID

PARAMETER GIVEN BY REQUIREMENTLiquid type ;Hazardous/Flammable

Purchaser a flash point below 100 degrees Fahrenheit (38 degrees Celsius). Less-flammable liquids (with a flashpoint between 100 degrees and 200 degrees Fahrenheit) are defined as combustible liquids.

Pumping Temp. Purchaser The temperature at which the liquid is to be pumped.

Vapour Pressure Purchaser Vapor pressure or equilibrium vapour pressure is defined as the pressure exerted by a vapor in thermodynamic equilibrium with its condensed phases (solid or liquid) at a given temperature in a closed system. It is The property of the liquid .

Relative Density Purchaser Relative density, or specific gravity, is the ratio of the density (mass of a unit volume) of a substance to the density of a given reference material.It is the property of the liquid used

Viscosity Purchaser The viscosity of a fluid is a measure of its resistance to gradual deformation by shear stress or tensile stress. For liquids, it corresponds to the informal concept of "thickness"

Specific Heat Purchaser The specific heat is the amount of heat per unit mass required to raise the temperature by one degree Celsius. It is the property of the liquid.

Chloride Concentration Purchaser The concentration of these salts in the crude oil depends on the oil field from which the crude is extracted,

H2S concentration purchaser Total sulfur in a crude oil depends on the type of oil field and the conc with H2.

7.7 MATERIALS

PARAMETER GIVEN BY REQUIREMENTANNEX H CLASS Purchaser Materials and material

specifications for pump partsreduced hardness material required

Purchaser

Barrel case PurchaserImpeller PurchaserImpeller Wear Rings PurchaserShaft PurchaserDiffusers

7.8 PERFORMANCE

PARAMETER GIVEN BY REQUIREMENTProposal Curve No. Purchaser A pump can be selected by

combining the System Curve and the Pump Curve

Impeller dia(Rated/max./min)

Purchaser The calculations are based on the affinity laws which in turn are derived from a dimensionless analysis of three important parameters that describe pump performance . three things are Head , Flow and speed of impeller

Impeller type Purchaser Closed , open or semi open.Efficiency Purchaser Required efficiency that is

calculated using the pump curves and system curves

Rated Power Purchaser Power that is supplied for the impeller to produce the required efficiency

Min. continuous Flow(Thermal/Stable)

Purchaser The minimum rate of flow required to avoid problems like Cavitation

Preferred Operation Region Purchaser Range of operation where the efficiency obtained is maximum and cavitation is avoided

Max. head @rated impeller Purchaser Maximum head generated if the impeller runs at the given parameters

Max. Sound Pressure Level Required

Purchaser

7.9 UTILITY

PARAMETER GIVEN BY REQUIREMENTElectricity Purchaser Electricity requirement of the

driver used .Steam Purchaser The maximum /allowable

pressure of the steam used in the turbine (if a turbine is used)

Cooling water Purchaser Maximum and allowable temperature and pressure of the cooling water used in the turbine . a better cooling system provides a better efficiency of the turbine

7.10 CONSTRUCTION

PARAMETERRotation Purchaser Viewed from coupling endPump Type Purchaser Which type of pump

required .Casing Mounting(centreline/in-line/other)

Purchaser

Casing Type(Single Volute/Multi-volute/diffuser)

Purchaser

Max. Allowable working pressure

Purchaser The should be able to withstand design pressure.

Hydrotest Pressure Purchaser Pressure above the design pressure . Pipes are deformed

Nozzle Connection1)Size Purchaser The size of the nozzle is

dependent on the head that is to be provided.

2)Flange Rating Purchaser A flange is a connection between the main pipeline and the pump thus the pressure in the pipeline decides the flange rating. flange rating decides the flange size , the flange bolt size.

Coupling Manufacturer It includes Model , Rating , Spacer length , Type of coupling , coupling guard .

7.11 SURFACE PREPARATION AND PAINT

Parameter Given By RequirementPump Surface Preparation Purchaser Rp standardPrimer Purchaser Rp standardfinish coat purchaser Rp standard

7.12 HEATING AND COOLING Parameter Given By RequirementCooling water piping plan Purchaser Cooling water required for

pumping volatile liquids which become flammable at room temperature

C.W.Piping Material Purchaser The material is important as it indicates the efficiency of rate of cooling.

7.13 BEARINGS AND LUBRICATIONParameter Given RequirementBearing Type PurchaserLubrication Type PurchaserViscosity of Oil PurchaserOil Heater Requirement Purchaser If the liquid transported is at a

particular temperature then the lubricant used should be at the same temperature so

as to reduce the loss of energy .