pipeline planning and construction field manual

Units of measurement are generally divided into three classes as follows:Base units Supplementary units Derived units Base units are units that are dimensionally independent, such as uni

Pipeline Planning and Construction

Field Manual

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Pipeline Planning and

Construction Field

Manual

E Shashi Menon, Ph.D., P.E.

SYSTEK Technologies, Inc

AMSTERDAM • BOSTON • HEIDELBERG • LONDON

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This book and the individual contributions contained in it are protected under copyright by the Publisher (other than as may be noted herein).

Notices

Knowledge and best practice in this field are constantly changing As new research and experience broaden our understanding, changes in research methods, professional practices, or medical treatment may become necessary.

Practitioners and researchers must always rely on their own experience and knowledge in evaluating and using any information, methods, compounds, or experiments described herein In using such information or methods they should be mindful of their own safety and the safety of others, including parties for whom they have a professional responsibility.

To the fullest extent of the law, neither the Publisher nor the authors, contributors, or editors, assume any liability for any injury and/or damage to persons or property as a matter of products liability, negligence or otherwise, or from any use or operation of any methods, products, instructions, or ideas contained in the material herein.

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Pipeline planning and construction field manual / [edited by] E Shashi Menon, Ph.D., P.E.

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Printed in the United States of America

11 12 13 14 15 16 10 9 8 7 6 5 4 3 2 1

Contents

3 Pipeline Regulatory and Environmental Permits

William E Bauer

3.1.3 Safety Regulations of Oil, Gas, and Hazardous Materials

3.5.1 Identifying Permits and Determining Requirements

4.6.2 Condemnation Through the Power of Eminent Domain

Contentsvi

5.4 Stationing 84

7 Pipe Strength and Wall Thickness

E Shashi Menon, Ph.D., P.E

8 Pipeline Hydraulic Analysis

E Shashi Menon, Ph.D., P.E

9 Series and Parallel Piping and Power Required

E Shashi Menon, Ph.D., P.E

Contentsviii

10.13 Valve Maintenance for Liquid and Gas Pipelines

10.14 Overpressure Safety Valves and Pressure Limiting Devices

10.16 Pressure Limiting and Regulating Stations for Gas Pipelines 219

11.13 Effect of Specific Gravity and Viscosity on Pump

11.16 Multiple Pumps Versus System Head Curve 250

12.10 Types of Compressors– Centrifugal and Positive

15 Pipeline Pigging and Inspection

Barry G Bubar, P.E

15.12 Smart Pig Types 330

Contentsxii

17.13 Strength of Welded Pipelines 372

Barry G Bubar, P.E

19.7 Pipeline Drying 413

20 Specification Writing, Data Sheet Production,

Requisition Development, and Bid Analysis

21 Operations and Maintenance Manuals

21.5.7 Pump Station, Terminal, and Tank Farm

21.6 Maintenance Manuals 478

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Author Biography

E Shashi Menon, Ph.D., P.E.

E Shashi Menon is the vice president of SYSTEK Technologies, Inc in LakeHavasu City, Arizona, USA He has worked in the oil and gas and manufactur-ing industry for over 37 years He held positions of design engineer, projectengineer, engineering manager, and chief engineer with major oil and gas com-panies in the United States He has authored four technical books for major pub-lishers and coauthored over a dozen engineering software applications Heconducts training workshops in liquid and gas pipeline hydraulics at variouslocations in the United States and South America

Barry G Bubar, P.E.

Barry Bubar graduated from University of California with a BS degree inmechanical engineering He has worked in the petroleum pipeline industry as

a district engineer, project engineer and staff engineer and has over 35 yearsexperience in oil, gas, and power companies He has taught classes in pipelinehydraulics and pipeline welding and now works as a mechanical engineeringconsultant

William E Bauer

Bill Bauer has been associated with right-of-way acquisition projects for over

35 years He has managed the acquisition of pipeline rights-of-way, regulatorypermits, and associated actions throughout the continental United States,Alaska, Europe, and Russia He is a graduate of Lamar University, Beaumont,Texas, with a BS degree in Math and has written and/or edited numerous books,articles, and videos relating to right-of-way He is also a certified instructor forthe International Right-of-Way Association Bill has seen right-of-way acquisi-tion move from a hand shake, a signature, and a nominal payment to a highlytechnical effort sometimes approaching 25% or more of the total cost of a pipe-line project

Hal S Ozanne

Hal S Ozanne, BSME, is the vice president of Denver Operations of ENGlobalEngineering, Inc in Denver, Colorado, USA

xix

He has worked in the oil and gas industry for over 42 years His experiencehas included managing a division office for a consulting engineering firm pro-viding engineering services to the oil and gas industry, serving as project man-ager for various pipeline projects throughout the United States, and working for

a pipeline operating company in various capacities

Glenn A Wininger

Glenn Wininger graduated from Oklahoma State University with a BS degree incivil engineering in 1984 and a BS degree in biology in 1990 from Ohio StateUniversity He worked for numerous engineering firms with emphasis in cross-country pipeline projects and as a consultant for engineering firms related tolocal area gas distribution companies He held positions within gas companies

in engineering and construction management, as well as operations He assistedcompanies in compiling data for the Federal Energy Regulatory Committee(FERC) applications, as well as providing support for Draft EnvironmentalImpact Statement (DEIS) and Final Environmental Impact Statement (FEIS)response related to various requests He held a Registered Professional LandSurveyor (RPLS) license from 1986 to 1990

Author Biographyxx

There are thousands of pipelines crisscrossing the globe, both onshore andoffshore Designing, constructing, and operating these pipelines and theirappurtenant facilities require special skills along with experience Designcriteria and construction techniques differ from area to area and knowingwhere and how to access such criteria is essential for pipeline professionals.This book was prepared in order to give engineers and technicians a work-ing knowledge of the processes of planning, designing, and construction of apipeline system The idea for the book was conceived by Elsevier Senior Acqui-sitions Editor, Kenneth McCombs, in consultation with Shashi Menon, a pro-fessional engineer with over 37 years of experience in the US Oil and Gasindustry In addition, we assembled a team of experts with over 180 years com-bined experience throughout the United States and the world to collaborate onthe book and produce a relevant and useful reference manual for pipeline plan-ning and construction

Chapter 1 covers the design basis that forms the foundation for the design ofpipelines, pump stations, compressor stations, valves, and other facilities thatcomprise the pipeline system

Chapter 2 introduces the various things that must be taken into consideration

in selecting a pipeline route and how a route may be selected and changed as it

is being developed

Chapter 3 reviews pipeline regulatory and environmental permits Thisincludes numerous permits and approvals that must be obtained from state,federal, and local agencies

Chapter 4 covers the right-of-way (ROW) aspects including the ity of ROW team to provide the project a continuous constructible strip of landfor the construction of the pipeline and all related surface facilities, including acontinuous pipeline right-of-way, all additional work spaces, surface sites forcompressor stations, pump stations, meters, valves, and storage sites

responsibil-Chapter 5 describes how pipeline alignment sheets are prepared, the mation that is included on them and their use

infor-Chapter 6 is an overview of pipeline materials The chapter describes howmaterials for a pipeline are selected taking into consideration the pipeline service,operating conditions, and the appropriate regulations that must be followed.Chapter 7 is a discussion of the strength capabilities of a pipeline that is sub-ject to internal pressure and how the required pipe wall thickness is calculated.Chapter 8 explains pipeline hydraulic analysis for both liquid and gas pipe-lines The chapter reviews the different types of flow, Reynolds number, and

xxi

pressure drop due to friction and determining pumping pressure requirementsand location of pump stations and compressor stations.

Chapter 9 covers the calculation of the pressure required in series and allel piping In addition, the pumping power required and the number of pumps

par-or compresspar-or stations needed fpar-or a long transmission pipeline are discussed.Chapter 10 reviews requirements of multiple valve stations along a pipelinenecessary for isolating segments of pipelines for repair work and in case of aleak, damage, or rupture In addition, valves installed at pipeline branch connec-tions for delivery or receipt of product being shipped on the mainline are alsodiscussed

Chapter 11 explains the pump stations and pumping configurations in liquidpipelines along with the optimum locations of pump stations for hydraulicbalance Centrifugal pumps and positive displacement pumps and their perfor-mance characteristics are reviewed The use of variable speed pumps to savepumping power under different operating conditions is also discussed.Chapter 12 explains the approach to sizing compressor stations in gas pipe-lines The optimum locations and pressures at which compressor stations oper-ate are reviewed Centrifugal and positive displacement compressors used innatural gas transportation are compared with reference to their performancecharacteristics and cost

Chapter 13 discusses pipeline corrosion, how corrosion occurs, and themethod employed to protect liquid and gas pipelines and associated facilitiesfrom corrosion damage

Chapter 14 introduces the provisions for leak detection for a pipeline line operators must take the necessary preparations to eliminate or greatlyreduce the possibility of a leak from their system

Pipe-Chapter 15 discusses pipeline pigging and internal inspection Pigging of apipeline is essential for effective and efficient operation and maintenance Thisresults in increased pipeline efficiency and extends its useful life

Chapter 16 discusses pipeline construction with reference to federal, state,district, and local regulations

Chapter 17 discusses welding and nondestructive testing (NDT) of liquidand gas pipelines Pipe welding procedures, double jointing, welder qualifica-tion, automatic welding, radiography, weld rejection criteria are reviewed.Chapter 18 discusses hydrostatic testing to ensure integrity of pipeline inservice The federal regulations such as CFR Title 49, Part 195 for HazardousLiquid Pipelines and CFR Title 49, Part 192 for Gas Pipelines are reviewed.Chapter 19 describes the preparation and steps to commission or place apipeline into operation

Chapter 20 covers specification writing, data sheet production, requisitiondevelopment, and bid analysis for pipeline materials and equipment

Chapter 21 describes the information that is included in operations andmaintenance manuals and the preparation of these manuals

Prefacexxii

The authors would like to acknowledge the many suggestions andconstructive comments received from their peers who reviewed portions of themanuscript Special thanks to David W Sinclair for his assistance in the review

of Chapters 3 and 4 of this manual Mr Sinclair, a right-of-way executive formore than 30 years, has been a strong supporter of education and professionalismthrough the International Right of Way Association (IRWA) In addition,the authors would like to thank their families for being understanding duringthe many hours spent writing, revising, and proofreading the manuscript andsubsequent page proofs

We would like to take this opportunity to thank Kenneth McCombs, SeniorAcquisitions Editor of Elsevier Publishing, for suggesting the subject matterand format for the book We enjoyed working with him, as well as others, atElsevier such as Jill Leonard (Editorial Project Manager) and Heather Tighe(Associate Project Manager)

Authors have exercised care and diligence to contact copyright holders forpermission to use published reference materials We have also worked hard

to eliminate errors and omissions Readers are encouraged to independentlycheck calculations and verify results prior to using them in their projects Wewelcome notifications of corrections and suggestions for improvement of thisfield manual in subsequent edition

E Shashi MenonBarry G BubarWilliam E BauerHal S OzanneGlenn A Wininger

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First, we review the units of measurement used in the pipeline industry Thevarious units of measurement and calculations used in the United States ofAmerica, Canada, and other countries will be discussed and the conversionbetween the commonly used units explained Next, we address the physicalproperties of fluids (liquids and gases) that are transported in the pipeline.Chapters 7–9 will further describe the details of the pipeline design basis byanalyzing the major components such as pipes, valves, pumps, compressors,and ancillary equipment An outline of the various components that constitute

a DBM is also provided in Appendix 1

Pipeline Planning and Construction Field Manual

1

1.1 UNITS OF MEASUREMENT

The units of measurement employed in the pipeline transportation industry sist mainly of the English or USCS system of units (US Customary System) andthe metric or SI (Système International) system of units USCS units are usedexclusively in the United States of America, whereas SI units are used in thecountries that use metric units, such as Europe, Asia, Australia, and SouthAmerica In Canada and some South American countries, a combination ofUSCS and SI units are used

con-In USCS units, measurements are derived from the old second (FPS) and foot-slug-second (FSS) system that originated in England.The basic units are foot (ft) for length, slug (slug) for mass, and second (s)for measurement of time

foot-pound-In SI units, the corresponding units for length, mass, and time are meter (m),kilogram (kg), and second (s), respectively In both USCS and SI units, time has

a common unit of second

Units of measurement are generally divided into three classes as follows:Base units

Supplementary units

Derived units

Base units are units that are dimensionally independent, such as units oflength, mass, time, electric current, temperature, amount of substance, and lumi-nous intensity

Supplementary units include those used to measure plain angles and solidangles, such as radian and steradian

Derived units are formed by combining base units, supplementary units, andother derived units Examples are force, pressure, and energy

Electric current– ampere (A)

Temperature– degree Fahrenheit (°F)

Amount of substance– mole (mol)

Luminous intensity– candela (cd)

In SI units, the base units are as follows:

Electric current– ampere (A)

Temperature– Kelvin (K)

Amount of substance– mole (mol)

Luminous intensity– candela (cd)

1.1.2 Supplementary Units

In USCS and SI units, the supplementary units are as follows:

Plain angle– radian (rad)

Solid angle– steradian (sr)

Radian is defined as the plain angle between two radii of a circle with an arclength equal to the radius Thus, it represents the angle of a sector of a circlewith the arc length equal to its radius

One radian= ð180/πÞ degrees = 57:3 degrees ðdegÞ

Since a circle contains 360 degrees, this is equivalent to

ð360/57:3Þ = 2π radians = 6:28 radThe steradian is the solid angle having its apex at the center of a sphere suchthat the area of the surface of the sphere that it cuts out is equal to that of asquare with sides equal to the radius of this sphere

1.1.3 Derived Units

Derived units are those that are formed by combining base units, supplementaryunits, and other derived units For example, area and volume are derived unitsformed by combination of the base unit length Similarly, velocity (or speed) isderived from the base unit of length and time It is important to note thatnumerically velocity and speed are the same, but velocity is a vector quantity,whereas speed is a scalar quantity A vector has both magnitude and direction,whereas a scalar has only magnitude

In USCS units, the following derived units are used:

Area– square inches (in2

), square feet (ft2)Volume– cubic inches (in3

), cubic feet (ft3), gallons (gal), and barrels (bbl)Speed/velocity– feet per second (ft/s)

Acceleration– feet per second per second (ft/s2

)Density– slug per cubic foot (slug/ft3)

Specific weight– pound per cubic foot (lb/ft3)

Specific volume– cubic feet per pound (ft3/lb)

Dynamic viscosity– pound second per square foot (lb· s/ft2)

Kinematic viscosity– square feet per second (ft2/s)

Force– pounds (lb)

Pressure– pounds per square inch (lb/in2or psi)

Energy/work– foot pound (ft ·lb)

Quantity of heat– British Thermal Units (Btu)

Power– Horsepower (HP)

Specific heat– Btu per pound per °F (Btu/lb/°F)

Thermal conductivity– Btu per hour per foot per °F (Btu/h/ft/°F)

In SI units, the derived units are as follows:

Area– square meters (m2)

Volume– cubic meters (m3)

Speed/velocity– meter per second (m/s)

Acceleration– meter per second per second (m/s2)

Density– kilogram per cubic meter (kg/m3)

Specific volume– cubic meters per kilogram (m3/kg)

Force– Newton (N)

Pressure– Newton per square meter (N/m2

) or Pascal (Pa)Dynamic viscosity– Pascal second (Pa·s)

Kinematic viscosity– square meters per second (m2

/s)Energy/work– Newton meter (N·m) or joule (J)

Quantity of heat– joule (J)

Power– joule per second (J/s) or watt (W)

Specific heat– joule per kilogram per Kelvin (J/kg/K)

Thermal conductivity– joule per second per meter per Kelvin (J/s/m/K) or(W/m/K)

Other derived units used in USCS and SI units and the conversion betweenvarious units are listed in Appendix 1

1.2 PHYSICAL PROPERTIES OF LIQUIDS AND GASES

Since pipelines are used to transport liquids or gases (collectively referred to asfluids), we discuss some important physical properties of fluids that affect pipe-line transportation In liquid pipelines, these include specific gravity, viscosity,specific heat, bulk modulus, and vapor pressure In compressible fluids, such asnatural gas pipelines, the important properties are specific gravity, viscosity,molecular composition, heating value, specific heat, and the compressibilityfactor These physical properties and how they are calculated including methodsbetween various units will be illustrated using examples The variation of theseproperties with the temperature and pressure of the fluid is important in bothliquid and gas pipelines In heavy crude oil pipelines, sometimes, the crudeoil is heated to reduce viscosity and thus improve pumpability This, in turn,reduces power requirements and hence cost of transportation Therefore, thevariation in viscosity and gravity with temperature become very important.Sometimes, a low-viscosity product (such as a diluent or light crude oil) is

CHAPTER | 1 Design Basis4

blended with a heavy crude oil to reduce the viscosity and enhance pumpability.

We explain the methods commonly used to determine the blended properties oftwo or more liquids Similarly for gases, knowing the molecular composition ofindividual gases, we explain the method of calculating the composition of thegas mixture and the corresponding gravity and viscosity

This chapter forms the foundation for all calculations for designing andplanning the pipelines used to transport liquids and gases These include pres-sure drop due to friction in pipes, valves, and fittings, as well as pump andcompressor power requirements, all of which will be addressed in Chapters 8through 12 In Appendix 1, tables are included listing physical properties ofcommonly transported liquids and gases such as water, refined petroleum pro-ducts, crude oils, and natural gas

1.2.1 Liquid Properties

Mass, Weight, Volume, and Density

For both liquids and gases, mass, weight, volume, and density are discussed inthis section and the related terms specific volume and specific weight are alsoexplained

Massis defined as the quantity of matter in a substance and it does not varywith temperature or pressure It is a scalar quantity and hence has magnitude but

no direction, compared to a vector quantity that has both magnitude and tion Mass is measured in slug (slug) in USCS units and kilograms (kg) in SIunits The term weight depends on the mass and acceleration due to gravity

direc-at a particular locdirec-ation and is a vector quantity Weight is actually the force ing on a mass and hence is a derived unit In USCS units, weight is stated inpounds (lb) and in SI units it is measured in Newton (N) The quantity of liquidcontained in a storage tank may be referred to as 5000 lb weight This is some-times referred to incorrectly as 5000 lb mass of liquid The correct term would

act-be to say the mass of liquid contained in the tank is 5000/32.17= 155.4 slug.The factor 32.17 represents the acceleration due to gravity (32.17 ft/s2) This

is based on Newton’s second law of motion, represented by the followingrelationship:

Since force has the units of lb, from Eq (1.1) it is clear that slug has theunits of lb·s2/ft

Similarly, in SI units, if a storage tank contains 170 kg of crude oil, this isthe mass of the crude oil Its weight in Newton is 170× 9:81 = 1667:7 N.The factor 9.81 is the acceleration due to gravity (9.81 m/s2) in SI units.However, in common usage we tend to say (incorrectly) that the weight ofcrude oil in the tank is 170 kg

Volumeis defined as the space occupied by a given mass In the case of aliquid in a tank, the liquid fills the tank up to a certain height In comparison, a

compressible fluid such as natural gas will fill an entire sphere or bullet used as

a storage vessel Thus, gas expands to fill its container Consider a cylindricalstorage tank for gasoline, if the inside diameter of the tank is 100 ft, the cross-sectional area is

a liquid In the gasoline storage tank example, if the temperature of gasolineincreases from 60°F to 80°F, the liquid volume will increase slightly therebyraising the height of the liquid level in the tank The amount of increase involume per unit temperature rise depends on the coefficient of expansion ofthe liquid Therefore, when measuring petroleum liquids, for the purpose of cus-tody transfer, it is customary to correct volumes to a fixed temperature such as

60°F (15.6°C) Volume correction factors from American Petroleum Institute(API) publications are commonly used in the petroleum industry

The volume of a gas is also sensitive to both temperature and pressure.Therefore, a standard temperature, such as 60°F (15.6°C), is used when refer-ring to gas volumes in pipelines

The volume flow rate in a liquid pipeline (or pipeline throughput) is stated incubic feet per second (ft3/s), gallons per minute (gal/min), barrels per hour (bbl/h),

or barrels per day (bbl/day) in USCS units

CHAPTER | 1 Design Basis6

In SI units, liquid flow rate is stated in cubic meters per hour (m3/h) or litersper second (L/s) Similarly, gas flow rate is measured in cubic meters per hour

or million cubic meters per day (Mm3/day) Also, in gas pipeline terminology,standard volumes are used based on a reference temperature of 60°F (15.6°C).This is discussed further in section 1.2.2

In a liquid pipeline, it is customary to talk about the“line fill volume” of thepipeline This is the volume of liquid contained between any two points alongthe length of the pipeline The volume of liquid contained between two valves

on a pipeline can be calculated by knowing the internal diameter of the pipe andthe length of the pipe segment between the two valves

For example, consider a pipeline of NPS 20 with an outside diameter of 20 in.and 0.500 in wall thickness The line fill volume in a 5000-foot-long section ofthe pipeline is

Line fill volume= ðπ/4Þ × ð20 − 2 × 0:500Þ2× 5000/144 = 9844:77 ft3

This is also equal to

ð9844:77 × 1728/231Þ = 73,644 gal or 1753:43 bbl

The above calculation is based on conversion factors of 1728 in3/ft3and 42 gal/bbl.Since the volume of a liquid varies with temperature, in a liquid trans-mission pipeline, the inlet flow rate measured at the inlet temperature and theoutlet flow rate measured at the outlet temperature may be different in along-distance pipeline, even if there are no intermediate flow injections or deliv-eries This is because the inlet temperature of the liquid will be different fromthe outlet temperature due to heat loss or gain between the pipeline liquid andthe surrounding soil in a buried pipeline Significant variation in temperaturemay be observed when pumping crude oils or other products that are heated

at the pipeline inlet In refined petroleum products pipelines, such as gasolineand diesel, no heating occurs at the pipe inlet and therefore the temperature var-iations along the pipeline may be insignificant Regardless, if the volume flowrate measured at the pipeline inlet is corrected to a standard temperature such as

60°F (or 15°C), the corresponding outlet volume flow rate can also be corrected

to the same standard temperature With this temperature correction, the flowrate throughout the pipeline from inlet to outlet will be the same, providedthere are no intermediate injections or deliveries along the pipeline Due tothe principle of conservation of mass, the mass flow rate throughout the pipelinewill be the same regardless of temperature variation from inlet to outlet,provided there are no intermediate injections or deliveries along the pipeline.Densityof a liquid is a measure of how densely packed its molecules are in

a given volume Mass density is calculated by dividing the mass by its volume

In USCS units, mass density is stated as slug/ft3 In SI units, mass density

is stated as kg/m3 Similarly, the weight density is defined as the weightper unit volume Weight density is more commonly called specific weight

For example, the specific weight of water is 62.4 lb/ft3at 60°F In comparison, atypical diesel fuel has a weight density of 53.6 lb/ft3.

In SI units, the mass density of a sample of water may be stated as 1000 kg/m3

at 15°C

Weight densityðspecific weightÞ = weight/volume (1.3)Although mass does not change with temperature, compared to volume, themass density will vary with the temperature of the liquid Density and volumeare inversely related from Eq (1.3) Therefore, as temperature increases, liquidvolume increases while its density decreases Similarly, as temperaturedecreases, liquid volume decreases and its density increases Similar to volume,the density of a liquid varies very slightly with pressure This is because mostliquids are practically incompressible, compared to gases

Specific Gravity and API Gravity of Liquids

The specific gravity of a liquid is a measure of how heavy a liquid is compared

to water Therefore, it is the ratio of the liquid density to that of water at thesame temperature Being a ratio of similar units, specific gravity is dimension-less and has no units By definition, the specific gravity of water is 1.00, sincethe density of water compared to itself is the same

The term relative density is also used synonymously with specific gravity.For example, at 60°F water has a density of 62.4 lb/ft3compared to a density

of 46.2 lb/ft3for gasoline The relative density of gasoline at this temperature istherefore 46.2/62.4= 0.74 This is also called the specific gravity of gasoline at

60°F As another example, at 15°C, a certain crude oil has a density of 890 kg/m3

tem-In the petroleum industry, in addition to specific gravity, the term API ity (°API) is also used The API gravity is a scale of measurement, such that forwater API= 10 at 60°F Liquids lighter than water have API values higherthan 10 Thus, a typical diesel has an API gravity of 35°API The API scale

grav-is thus an inverse scale compared to specific gravity and grav-is always stated at

60°F The API value is determined in the laboratory comparing the density

of a liquid with the density of water at 60°F As another example, gasolinehas an API gravity of 59.7°API, whereas a typical crude oil has 35°API

CHAPTER | 1 Design Basis8

The relationship between API gravity and specific gravity are stated inEqs (1.4) and (1.5):

Specific gravity Sg= 141:5/ð131:5 + APIÞ (1.4)

Setting API gravity equals 10 for water in Eq (1.4) gives a specific gravity

of 1.00 for water, as expected Note that, if specific gravity> 1.076, the APIvalue is negative; therefore, to use the above equations, the specific gravitymust be less than 1.076

The specific gravity of a typical gasoline at 60°F is 0.736 Therefore, its APIgravity can be calculated from Eq (1.5) as follows:

API gravity= 141:5/0:736 − 131:5 = 60:76°API

Conversely, if a certain crude oil has an API gravity of 35, its specific gravitycan be calculated from Eq (1.4) as follows:

Specific gravity= 141:5/ð131:5 + 35Þ = 0:8498

It is important to remember that API gravity is always measured at 60°F.Therefore in Eqs (1.4) and (1.5), the value of specific gravity used must be

at 60°F It is meaningless to say that the API gravity of a liquid is 35°API at

70°F, because by definition API is always measured in the laboratory at 60°F.The API gravity of a liquid is measured in the laboratory in accordance withthe method described in the ASTM D1298 standard, using a calibrated glasshydrometer For further discussion on API gravity, refer to the API Manual

of Petroleum Measurements

Liquid Specific Gravity: Variation with Temperature

The specific gravity of a liquid varies with temperature It increases withdecrease in temperature and vice versa For commonly encountered tempera-tures in liquid transmission pipelines, the specific gravity of a liquid variesapproximately linearly with temperature Therefore, a 10% increase in tempera-ture results in a 10% decrease in specific gravity The specific gravity versustemperature can therefore be expressed approximately as follows:

a – A constant that depends on the liquid

Suppose the specific gravity of a liquid at 70°F and 80°F are known Thesetwo sets of temperature and specific gravity can be substituted in Eq (1.6)resulting in two simultaneous equations in the unknowns S60and a By solvingthe two simultaneous equations, the values of S60 and a can be obtained Wecan then determine the specific gravity of the liquid at any other temperatureusing Eq (1.6).

Liquid Specific Gravity: Blended Products

Sometimes, two liquids are mixed together to form a homogeneous liquid ture If we know the specific gravity of each component, at a common tempera-ture, the specific gravity of the blended mixture can be calculated at the sametemperature

mix-Consider a crude oil of specific gravity 0.895 at 70°F blended with a lightercrude oil of specific gravity 0.815 at 70°F in equal volumes What is the specificgravity of the blended mixture? Common sense suggests that since equalvolumes are used, the resultant mixture should have a specific gravity of theaverage of the two liquids or

ð0:895 + 0:815Þ/2 = 0:855When two or more liquids are blended to form a homogenous mixture, thespecific gravity of the mixture can be calculated using the weighted averagemethod For example, if a mixture is formed by blending 10% of liquid A (spe-cific gravity= 0.85) and 90% of liquid B (specific gravity = 0.89), the specificgravity of the resulting blended liquid is

ð0:1 × 0:85Þ + ð0:9 × 0:89Þ = 0:886When calculating the blended specific gravity of two or more products, thespecific gravity values must be measured at the same temperature A generalequation to calculate the specific gravity of a blended mixture of two ormore products is as follows:

Sb= ½ðQ1S1Þ + ðQ2S2Þ + …/ðQ1+ Q2+ …Þ (1.7)where

Sb– Specific gravity of the blended liquid

Q1, Q2, etc – Volume of each component

S1, S2, etc.– Specific gravity of each component

The above method of calculating the specific gravity of a mixture of two ormore liquids cannot be used directly with API gravities The API gravities mustfirst be converted to the corresponding specific gravities at 60°F and theweighted average method applied After calculating the blended specific grav-ity, the API gravity of the mixture can be determined using Eq (1.5)

CHAPTER | 1 Design Basis10

Example Problem 1.1

Three liquids A, B, and C are blended homogenously in the ratio of 15%, 20%, and 65%, respectively, by volume Calculate the specific gravity of the blended liquid,

if the individual liquids have the following specific gravities at 70 °F:

Specific gravity of liquid A: 0.815

Specific gravity of liquid B: 0.850

Specific gravity of liquid C: 0.895

by its density at the same temperature

In SI units,μ is stated as kg/m·s, Pascal·s (or Poise), or centipoise (cP) Theterm Pascal (Pa) is the unit of pressure in SI units and is equal to N/m2.Kinematic viscosityν is stated as ft2

/s in USCS units and m2/s in SI units.Appendix 1 lists various conversion factors for viscosity units Other com-monly used units for kinematic viscosity include stokes (St) and centistokes(cSt)

If the viscosities are in cP and cSt, the relationship with the specific gravity

of the liquid Sg is

Viscosity, cSt= ðViscosity, cPÞ/Sg (1.9)Therefore, for a crude oil with a specific gravity of 0.89 and dynamicviscosity μ = 38 cP, kinematic viscosity is calculated from Eq (1.9) as

ν = 38=0:89 = 42:7 cSt

In the petroleum industry, two additional kinematic viscosity units forliquids are used These are Saybolt Seconds Universal (SSU) and Saybolt Sec-onds Furol (SSF) These are used in conjunction with heavy crude oils and fueloils Similar to specific gravity, the dynamic and kinematic viscosities of aliquid also vary with temperature The viscosity of a liquid decreases as tem-perature increases and vice versa However, unlike specific gravity, the viscos-ity versus temperature is not a linear relationship In addition, the viscosity of aliquid also varies slightly with pressures In the normally encountered range ofpressures in liquid transmission pipelines, the variation of liquid viscosity withpressures is insignificant However, at pressures in the range of 2000–5000 psi

or more, liquid viscosity increases with pressure

Water has a viscosity of 1.0 cP (dynamic viscosity) or 1.0 cSt (kinematicviscosity) at 60°F In comparison, Alaskan North Slope (ANS) crude oil has

a viscosity of 200 SSU (43.33 cSt) at 60°F Values of viscosity in SSU andSSF may be converted to their equivalent kinematic viscosity in centistokesusing the following equations

Conversion from SSU to centistokes:

Centistokes= 0:226 ðSSUÞ − 195/ðSSUÞ for 32 ≤ SSU ≤ 100 (1.10)Centistokes= 0:220 ðSSUÞ − 135/ðSSUÞ for SSU > 100 (1.11)Conversion from SSF to centistokes:

Centistokes= 2:24 ðSSFÞ − 184/ðSSFÞ for 25 < SSF ≤ 40 (1.12)Centistokes= 2:16 ðSSFÞ − 60/ðSSFÞ for SSF > 40 (1.13)The viscosities of common liquids are shown in Appendix 1 Also, Appendix 1includes conversion factors for converting viscosity from one set of units toanother

CHAPTER | 1 Design Basis12

Liquid Viscosity: Variation with Temperature

The viscosity of a liquid decreases as the temperature increases and vice versa.However, the variation is not linear, but it is logarithmic in nature as follows:

T = ðt + 273Þ K for temperature t in °C (1.15a)

A and B are constants that depend on the specific liquid

It can be seen from Eq (1.14) that a graphic plot of loge(ν) against thetemperature T will result in a straight line with a slope of−B If we are giventwo sets of viscosity and temperature data for a liquid, A and B values can bedetermined by substituting the two sets of viscosity and temperature data in

Eq (1.14) and solving the resulting simultaneous equations Once A and B arecalculated, the viscosity of the liquid at any other temperature can be determinedusing Eq (1.14)

Example Problem 1.2

The kinematic viscosities of a liquid at 60 °F and 100°F are 43 cSt and 10 cSt, respectively Using Eq (1.13), determine the values of constants A and B and the viscosity of the liquid at 80 °F.

logeð43Þ = A − B ð60 + 460Þ and

logeð10Þ = A − B ð100 + 460Þ Solution

Solving the above two equations for A and B results in

A = 22:7232 B = 0:0365 Having found A and B, we can now calculate the viscosity of this liquid at any other temperature using Eq (1.13) Therefore, the viscosity at 80 °F is calculated as follows:

logeðνÞ = 22:7232 − 0:0365 ð80 + 460Þ = 3:0132

Viscosity at 80 °F = 20:35 cSt

Several other methods are available to predict the viscosity variation of leum liquids with temperature The most popular of these is known as the ASTMD341 method In this method, a special graph paper with logarithmic scales is used

petro-to plot the viscosity of a liquid at two known temperatures A line is then drawnconnecting the two points on the graph The viscosity at any intermediate tempera-ture can then be interpolated To some extent, viscosity outside the range may also

be extrapolated from this chart Figure 1.1 illustrates the method

Appendix 1 provides the equations to manually calculate the viscosity versus perature using the ASTM method, without using the special logarithmic graph paper.

FIGURE 1.1 ASTM D341: Viscosity –temperature chart.

CHAPTER | 1 Design Basis14

1 At the first temperature 60 °F

C, D, and Z are calculated using Eqs (A 1.6) through (A 1.8) in Appendix 1.

C 1 = exp ½−1:14883 − 2:65868 × 750 = 0

D1= exp ½− 0:0038138 − 12:5645 × 750 = 0

Z1= ð750 + 0:7Þ = 750:7 Similarly, at the second temperature 180 °F, the corresponding values of C, D, and Z are calculated to be

C 2 = exp ½− 1:14883 − 2:65868 × 25 = 0

D 2 = exp ½− 0:0038138 − 12:5645 × 25 = 0

Z2 = ð25 + 0:7Þ = 25:7 Substituting in Eq (A 1.5) we get

log10log10ð750:7Þ = A − B logð60 + 460Þ

and for the second temperature

log10log10ð25:7Þ = A − B logð180 + 460Þ

Solving the simultaneous Eqs (1.16) and (1.17) for A and B, we get

A = 9:778

B = 3:4313

2 Using Eq (A 1.5), at 85 °F, we calculate the value of Z as follows:

log10log10ðZÞ = A − B logð85 + 460Þ log10log10ðZÞ = 9:778 − 3:4313 × 2:7364 = 0:3886

Z = 279:78 Therefore,

Viscosity at 85 °F = 279:78 − 0:7 = 279:08 cSt

Liquid Viscosity: Blended Products

Frequently, in the petroleum industry, two or more products are blended to form

a homogenous mixture A heavy crude oil may be mixed with a lighter product

to form a mixture with an intermediate viscosity, which will then be easier topump through a pipeline Consider a crude oil with a viscosity 89 cSt at

60°F blended with a lighter crude oil with a viscosity 15 cSt at 60°F, inequal volumes We need to determine the viscosity of the blended mixture.Due to the nonlinear nature of viscosity with mass and volume, we cannot aver-age the viscosities as we did with specific gravities blending earlier We mustresort to a different approach